NASDAQ NASDAQ 0001703785 false 0001703785 2022-06-07 2022-06-07 0001703785 dei:FormerAddressMember 2022-06-07 2022-06-07 0001703785 str:ClassCommonStockParValue0.0001PerShareMember 2022-06-07 2022-06-07 0001703785 str:WarrantsEachToPurchaseOneShareClassCommonStockMember 2022-06-07 2022-06-07

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

FORM 8-K

 

 

CURRENT REPORT

Pursuant to Section 13 OR 15(d)

of The Securities Exchange Act of 1934

Date of Report (Date of earliest event reported): June 7, 2022

 

 

SITIO ROYALTIES CORP.

(Exact name of registrant as specified in its charter)

 

 

 

Delaware   001-38158   82-0820780

(State or other jurisdiction

of incorporation)

 

(Commission

File Number)

 

(IRS Employer

Identification No.)

 

1401 Lawrence Street, Suite 1750

Denver, Colorado 80202

(Address of principal executive offices) (Zip Code)

Registrant’s telephone number, including area code: (720) 640-7620

609 Main Street, Suite 3950

Houston, Texas 77002

(Former Name or Former Address, if Changed Since Last Report)

 

 

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

 

Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

 

Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

 

Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

 

Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Securities registered pursuant to Section 12(b) of the Act:

 

Title of each class

  

Trading

Symbol(s)

  

Name of each exchange

on which registered

Class A common stock, $0.0001 par value    STR    Nasdaq Capital Market
Warrants, each to purchase one share of Class A common stock    STRDW    Nasdaq Capital Market

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).

Emerging growth company  ☒

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.  ☐

 

 

 


Introductory Note

On June 7, 2022 (the “Closing Date”), Sitio Royalties Corp., a Delaware corporation (formerly known as Falcon Minerals Corporation) (the “Company”), consummated the previously announced merger transactions contemplated by the Agreement and Plan of Merger, dated as of January 11, 2022 (the “Merger Agreement”), by and among the Company, Sitio Royalties Operating Partnership, LP, a Delaware limited partnership (formerly known as Falcon Minerals Operating Partnership, LP) (“Sitio OpCo”), Ferrari Merger Sub A LLC, a Delaware limited liability company (“Merger Sub”), and DPM HoldCo, LLC, a Delaware limited liability company (“Desert Peak”), pursuant to which Merger Sub merged with and into Desert Peak (the “Merger”), with Desert Peak continuing as the surviving entity in the Merger as a wholly owned subsidiary of Sitio OpCo. The transactions contemplated by the Merger Agreement are referred to herein as the “Merger Transactions.”

Prior to the effective time of the Merger (the “Merger Effective Time”), on June 3, 2022, the Company filed with the Secretary of State of the State of Delaware the Third Amended and Restated Certificate of Incorporation to effect the previously announced four to one reverse stock split (the “Reverse Stock Split”) for all of the Company’s issued and outstanding shares of common stock and outstanding equity awards. As a result of the Reverse Stock Split, every four shares of the Company’s issued and outstanding Class C Common Stock, par value $0.0001 per shares (“Class C Common Stock”) were automatically converted into one share of Class C Common Stock, without any change in the par value per share, and every four shares of the Company’s Class A Common Stock, par value $0.0001 per share (“Class A Common Stock” and, together with the Class C Common Stock, the “Common Stock”) were automatically converted into one share of Class A Common Stock, without any change in the par value per share. No fractional shares were outstanding following the Reverse Stock Split. In lieu of any fractional share, any holder of Class C Common Stock, who would have otherwise received less than one share of Class C Common Stock received cash equal to the fair value of such holder’s fractional share as determined by the Company’s board of directors (the “Board”). In lieu of any fractional share of Class A Common Stock, the transfer agent for the Class A Common Stock, as exchange agent, will aggregate and sell all fractional interests and will pay to stockholders that would have been entitled to such fractional shares their pro rata share of the net proceeds derived from the sale of such fractional interests. Additionally, as a result of the Reverse Stock Split, the Company’s outstanding warrants (the “Warrants”) were adjusted such that four of the Warrants became exercisable for one share of Class A Common Stock at an exercise price of $44.84 per share of Class A Common Stock. The Class A Common Stock began trading on a split-adjusted basis on the Nasdaq Capital Market LLC (“Nasdaq”) at the start of trading on June 6, 2022.

Pursuant to the terms of the Merger Agreement, at the Merger Effective Time and following effectiveness of the Reverse Stock Split, the limited liability company interests in Desert Peak issued and outstanding immediately prior to the Merger Effective Time were converted into the right to receive an aggregate of (a) 61,905,339 shares of Class C Common Stock and (b) 61,905,339 common units representing limited partner interests in Sitio OpCo (the “Sitio OpCo Partnership Units”) (the total amount under clauses (a) and (b), the “Merger Consideration”).

The Company’s stockholders immediately prior to the closing of the Merger Transactions (the “Closing”) continue to hold their shares of Class A Common Stock, subject to the Reverse Stock Split. As a result of the Merger Transactions, immediately following the Closing, (a) Chambers DPM HoldCo, LLC, a Delaware limited liability company (“Chambers”), and KMF DPM HoldCo, LLC, a Delaware limited liability company (“KMF” and, together with Chambers, “Kimmeridge”), together own approximately 43.5% of the issued and outstanding Common Stock, (b) Source Energy Leasehold, LP, a Delaware limited partnership (“Source”), and Permian Mineral Acquisitions, LP, a Delaware limited partnership (“Permian” and, together with Source, the “Source Stockholders”), together own approximately 15.4% of the issued and outstanding Common Stock, (c) Rock Ridge Royalty Company, LLC, a Delaware limited liability company (“Rock Ridge”), and Royal Resources L.P., a Delaware limited partnership (“Royal Resources” and, together with Rock Ridge, “Blackstone”), together own approximately 25.0% of the issued and outstanding Common Stock and (d) the Company’s remaining stockholders own approximately 16.1% of the issued and outstanding Common Stock. Following the Merger Transactions, including the Reverse Stock Split, there were 12,088,546 shares of Class A Common Stock outstanding, 71,752,285 shares of Class C Common Stock outstanding and 5,312,499 shares of Class A Common Stock issuable upon exercise of outstanding Warrants. There was no change to the number of authorized shares of Common Stock.

In connection with the filing of the Third Amended and Restated Certificate of Incorporation, the Company changed its name from “Falcon Minerals Corporation” to “Sitio Royalties Corp.” Unless the context otherwise requires, “Falcon” refers to the registrant prior to the Closing and “we,” “us,” “our,” and the “Company” refer to the registrant and its subsidiaries following the Closing.

 

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The Class A Common Stock and Warrants began trading on the Nasdaq at the start of trading on June 6, 2022 under the new symbols “STR” and “STRDW.” The Company expects the listing of its Class A Common Stock and Warrants to be transferred to the New York Stock Exchange (“NYSE”) and NYSE American LLC (“NYSE American”), respectively, on June 14, 2022 (the “Listing Transfer”), with the Class A Common Stock retaining the same ticker symbol and the Warrants trading under the new ticker symbol “STR WS.” The Class A Common Stock and Warrants will be delisted from Nasdaq.

 

Item 1.01.

Entry into a Material Definitive Agreement.

Director Designation Agreement

On the Closing Date, the Director Designation Agreement (the “Director Designation Agreement”), dated as of January 11, 2022, by and among the Company, Kimmeridge, Blackstone and the Source Stockholders became effective.

Pursuant to the Director Designation Agreement, the Company agreed to (a) include two nominees designated by the Company in the slate of nominees to be recommended by the Board for election at the first annual meeting of stockholders at which directors are to be elected following the Merger Effective Time and (b) include in the slate of nominees to be recommended by the Board for election at each applicable annual or special meeting of stockholders the following individuals: (i) so long as Kimmeridge (as defined in the Director Designation Agreement) collectively beneficially owns at least 10% of the outstanding shares of Common Stock, one nominee designated by Kimmeridge; (ii) so long as Blackstone and its affiliates collectively beneficially own at least 10% of the outstanding shares of Common Stock, one nominee designated by Blackstone; and (iii) so long as the Source Stockholders and its affiliates collectively beneficially own at least 10% of the outstanding shares of Common Stock, one nominee designated by the Source Stockholders.

On April 13, 2022, Blackstone executed a waiver pursuant to which it irrevocably waived its rights to designate its nominee for election to the Board pursuant to the Director Designation Agreement.

Under the Director Designation Agreement, no director designated by any of the Principal Stockholders (as defined in the Director Designation Agreement) shall, directly or indirectly, grant any proxy or enter into or agree to be bound by any voting trust, agreement or arrangement of any kind with respect to its shares of Common Stock that is inconsistent with or conflicts with the Director Designation Agreement.

The Director Designation Agreement terminates upon the earlier to occur of (a) the dissolution, liquidation or winding up of the Company, (b) with respect as to a party, when such party (including such party’s affiliates, as applicable) ceases to own at least 10% of the outstanding shares of Common Stock and (c) the termination of the Merger Agreement in accordance with its terms.

A description of the Director Designation Agreement is included in the Company’s definitive Proxy Statement, dated May 5, 2022 (the “Proxy Statement”), relating to the special meeting of the Company’s stockholders held on June 3, 2022 (the “Special Meeting”), in the section entitled “Related Agreements—Director Designation Agreement,” which is incorporated herein by reference. The foregoing description of the Director Designation Agreement is a summary only and is qualified in its entirety by reference to the full text of the Director Designation Agreement, a copy of which was filed with the SEC on January 12, 2022 as Exhibit 10.3 to Falcon’s Current Report on Form 8-K.

Registration Rights Agreement

On the Closing Date, the Registration Rights Agreement (the “Registration Rights Agreement”), dated as of January 11, 2022, by and among the Company, Kimmeridge, Blackstone and the Source Stockholders became effective as a result of the Closing.

 

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The Registration Rights Agreement will require the Company to (a) register for resale shares of the Company’s Class A Common Stock held by Kimmeridge, Blackstone and the Source Stockholders immediately following the Merger Effective Time, including any shares of Class A Common Stock issued or issuable upon the exchange of the shares of Class C Common Stock and Sitio OpCo Partnership Units held by Kimmeridge, Blackstone and the Source Stockholders immediately following the Merger Effective Time (the “Registrable Securities”), and (b) within 45 days following the Closing Date, file with the U.S. Securities and Exchange Commission (“SEC”) a registration statement registering the resale of all Registrable Securities permitted to be registered for resale from time to time.

Kimmeridge, Blackstone and the Source Stockholders will also receive certain “piggyback” registration rights to participate in underwritten offerings of the Company, subject to customary exceptions, and demand certain underwritten offerings.

A description of the Registration Rights Agreement is included in the Proxy Statement in the section entitled “Related Agreements—Restated Registration Rights Agreement,” which is incorporated herein by reference. The foregoing description of the Registration Rights Agreement is a summary only and is qualified in its entirety by reference to the Registration Rights Agreement, a copy of which was filed with the SEC on January 12, 2022 as Exhibit 10.2 to Falcon’s Current Report on Form 8-K.

Second Amended and Restated Agreement of Limited Partnership of Sitio OpCo

On June 7, 2022, the Company, Kimmeridge, Rock Ridge, Royal Resources and the Source Stockholders entered into the Second Amended and Restated Agreement of Limited Partnership of Sitio OpCo (as amended and restated, the “Sitio OpCo LPA”). The Sitio OpCo LPA amends and restates the existing Amended and Restated Agreement of Limited Partnership of Sitio OpCo (the “Falcon OpCo LPA”), dated as of August 23, 2018.

The Sitio OpCo LPA generally provides for certain tax and related structuring matters including, among other things, (a) revising Article III of the Falcon OpCo LPA to ensure the maintenance at all times of a one-to-one ratio between the number of Sitio OpCo Partnership Units owned by the Company and the number of outstanding shares of Class A Common Stock; and (b) revising Article XI of the Falcon OpCo LPA to (x) provide the Company a cash settlement option (as further described below) in connection with a redemption of Sitio OpCo Partnership Units pursuant to the Sitio OpCo LPA (“Redemptions”) and (y) provide additional parameters relating to the administration of Redemptions applicable to the limited partners of Sitio OpCo.

Furthermore, the Sitio OpCo LPA provides that, on the exercise by a limited partner of Sitio OpCo to redeem Sitio OpCo Partnership Units, Sitio OpCo will be entitled to settle any such redemption by delivering to the redeeming limited partner, in lieu of shares of Class A Common Stock, an amount of cash equal to: (a) other than in the case of clause (b), if the Class A Common Stock trades on a securities exchange or automated or electronic quotation system, the product of (x) the number of shares of Class A Common Stock that would have been received in such redemption and (y) the volume-weighted average price per share of Class A Common Stock for the five consecutive full trading days immediately prior to the delivery of the notice of redemption; (b) if the redemption is in connection with an underwritten offering to the public equity securities of the Company pursuant to a registration statement, the product of (x) the number of shares of Class A Common Stock that would have been received in such redemption and (y) the price per share of Class A Common Stock sold in such public offering (reduced by the amount of any discount associated with such share of Class A Common Stock); or (c) if the Class A Common Stock no longer trades on a securities exchange or automated or electronic quotation system, the product of (x) the number of shares of Class A Common Stock that would have been received in such redemption and (y) the fair market value of one share of Class A Common Stock as determined in good faith by the general partner of Sitio OpCo.

The foregoing description of the Sitio OpCo LPA is a summary only and is qualified in its entirety by reference to the Sitio OpCo LPA, a copy of which is attached as Exhibit 10.3 to this Current Report on Form 8-K and is incorporated herein by reference.

 

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Item 1.02.

Termination of a Material Definitive Agreement.

Shareholders’ Agreement

On the Closing Date, the Shareholders’ Agreement (the “Shareholders’ Agreement”), dated as of August 23, 2018, by and among the Company, Royal Resources Osprey Sponsor, LLC, a Delaware limited liability company (“Osprey Sponsor”), Edward Cohen, Jonathan Z. Cohen, Daniel C. Herz, Jeffrey F. Brotman, Royal Resources, Royal Resources GP L.L.C., a Delaware limited liability company (“Royal GP”), Noble Royalties Acquisition Co., LP, a Delaware limited partnership (“NRAC”), Hooks Ranch Holdings LP, a Delaware limited partnership (“Hooks Holdings”), DGK ORRI Holdings, LP, a Delaware limited partnership (“DGK Holdings”), and Blackstone Management Partners, L.L.C., a Delaware limited liability company (“Blackstone Management”), was terminated upon the consummation of the Merger Transactions and entry into the Director Designation Agreement.

The Shareholders’ Agreement provided that Blackstone Management was entitled to designate for nomination by the Company for election between one to six directors based on the percentage of voting power in the Company held by Blackstone Management and its controlled affiliates.

The foregoing description of the Shareholders’ Agreement is a summary only and is subject to, and qualified in its entirety by reference to, the full text of the Shareholders’ Agreement, a copy of which was filed with the SEC on August 29, 2018 as Exhibit 4.1 to Falcon’s Current Report on Form 8-K.

Falcon Credit Agreement

On the Closing Date and in connection with the Closing, the Company repaid its outstanding borrowings under the Credit Agreement, dated as of August 23, 2018, among Sitio OpCo, as the Borrower, the lenders from time to time party thereto, Citibank, N.A., as administrative agent and collateral agent for the lenders from time to time party thereto and each other issuing bank from time to time party thereto (the “Falcon Credit Agreement”) and terminated the Credit Agreement.

A description of the material terms of the Falcon Credit Agreement is contained in the Company’s Annual Report on Form 10-K for the year ended December 31, 2021 filed with the SEC on March 11, 2022, which description is incorporated herein by reference.

Amended and Restated Credit Agreement

On the Closing Date and in connection with the Closing, the Existing Credit Agreement (as defined below) was amended and restated in its entirety pursuant to a Second Amended and Restated Credit Agreement (as amended, restated, supplemented or otherwise modified from time to time, the “Credit Agreement”) entered into by Sitio OpCo, as borrower, KMF Land, LLC, a Delaware limited liability company (“KMF Land”), Bank of America, N.A., as the administrative agent and issuing bank, the lenders party thereto (the “Lenders”) and other financial institutions from time to time party thereto. In connection with the entry into the Credit Agreement, all amounts outstanding under the Existing Credit Agreement were repaid in full. The Credit Agreement is described under Item 2.03 below, which disclosure is incorporated into this Item 1.02 by reference. A description of the material terms of the Existing Credit Agreement is contained in the Proxy Statement in the section entitled “Management’s Discussion and Analysis of Financial Condition and Results of Operations of Desert Peak—Liquidity and Capital Resources—Our Revolving Credit Facility,” which description is incorporated herein by reference.

 

Item 2.01.

Completion of Acquisition or Disposition of Assets.

The disclosure set forth in the Introductory Note is incorporated into this Item 2.01 by reference.

On the Closing Date, the Company completed the Merger Transactions. At the Closing, pursuant to the Merger Agreement, the limited liability company interests in Desert Peak (the “DPM Membership Units”) converted into the right to receive an aggregate of (a) 61,905,339 shares of Class C Common Stock and (b) 61,905,339 Sitio OpCo Partnership Units. The holders of the DPM Membership Units (the “DPM Holders”) assigned their right to receive 0.5% of the Merger Consideration to the Company’s executive officers, as described in more detail under Item 3.02 below.

 

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The foregoing description of the Merger Agreement and the Merger Transactions is a summary only and is subject to, and qualified in its entirety by reference to, the full text of the Merger Agreement, a copy of which was filed with the SEC on January 12, 2022 as Exhibit 2.1 to Falcon’s Current Report on Form 8-K.

 

Item 2.03

Creation of a Direct Financial Obligation or an Obligation under an Off-Balance Sheet Arrangement.

On the Closing Date, Sitio OpCo entered into a financing agreement, as described herein.

Second Amended and Restated Credit Agreement

On October 8, 2021, KMF Land, as borrower, Desert Peak, as parent, Bank of America, N.A., as the administrative agent and issuing bank, and certain lenders entered into that certain Amended and Restated Credit Agreement (as amended, restated, supplemented or otherwise modified and as in effect immediately prior to the Closing Date, the “Existing Credit Agreement”), pursuant to which the lenders thereunder made loans and other extensions of credit to the borrower thereunder.

On the Closing Date, the Existing Credit Agreement was amended and restated in its entirety pursuant to the Credit Agreement entered into by Sitio OpCo, as borrower, KMF Land, Bank of America, N.A., as the administrative agent and issuing bank, the Lenders and other financial institutions from time to time party thereto. The Credit Agreement has a scheduled maturity date in June 2026.

Pursuant to the terms and conditions of the Credit Agreement, the Lenders committed to providing a credit facility to Sitio OpCo in an aggregate principal amount of up to $750 million. The availability under the Credit Agreement, including availability for letters of credit, is generally limited to a borrowing base, which is determined by the required number of lenders in good faith by calculating a loan value of the proved reserves of Sitio OpCo and its subsidiaries and elected commitments provided by the Lenders. As of the Closing Date, the Credit Agreement has a $300 million borrowing base and $300 million elected commitment amount. As part of the aggregate commitments under the revolving advances, the Credit Agreement provides for letters of credit to be issued at the request of the borrower in an aggregate amount not to exceed $15 million. Existing letters of credit in place under the Existing Credit Agreement immediately prior to the Closing Date are continued and now deemed issued under and governed by the terms of the Credit Agreement.

Interest accrues on advances, at the borrower’s option, at a Term SOFR rate or a base rate, plus an applicable margin. The fees for letters of credit are also based on the applicable margin. The applicable margin used in connection with interest rates and fees is based on the Borrowing Base Utilization Percentage (as defined in the Credit Agreement). The applicable margin for Term SOFR rate loans and letter of credit fees ranges from 2.500% to 3.500%, and the applicable margin for base rate loans ranges from 1.500% to 2.500%. The borrower will also pay a fee based on the borrowing base utilization percentage on the actual daily unused amount of the aggregate revolving commitments ranging from 0.375% to 0.500%.

The borrowings under the Credit Agreement are secured by liens on certain assets of the borrower, the borrower’s subsidiaries and Sitio Royalties GP, LLC, a Delaware limited liability company, and guaranteed by the borrower and the borrower’s subsidiaries. Proceeds from borrowings under the Credit Agreement may be used (i) for working capital, exploration and production operations, and other general company purposes including acquisitions, (ii) for payment of certain transaction fees and expenses, and (iii) to repay third party debt of the borrower and its subsidiaries existing prior to the Closing Date.

The Credit Agreement contains customary representations, warranties, covenants and events of default, including, among others, a change of control event of default and limitations on the incurrence of indebtedness and liens, new lines of business, mergers, transactions with affiliates and burdensome agreements. During the continuance of an event of default, the Lenders may take a number of actions, including, among others, declaring the entire amount then outstanding under the Credit Agreement to be due and payable.

The Credit Agreement includes a financial covenant limiting, as of the last day of each fiscal quarter, the ratio of (a) (i) Total Net Debt (as defined in the Credit Agreement) as of such date to (ii) EBITDA (as defined in the Credit Agreement) for the period of four fiscal quarters ending on such day (the “Leverage Ratio”), to not more than 3.50 to

 

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1.00, and (b) (i) consolidated current assets (including the available commitments under the Credit Agreement) to (ii) consolidated current liabilities (excluding current maturities under the Credit Agreement), to not less than 1.00 to 1.00, in each case, with certain rights to cure.

The above references to and description of the Credit Agreement do not purport to be complete and are qualified in their entirety by reference to the Credit Agreement, which is attached hereto as Exhibit 10.8 and is incorporated herein by reference.

 

Item 3.02.

Unregistered Sales of Equity Securities.

The disclosure set forth in the Introductory Note, Item 1.01, and Item 2.01, in so far as it relates to the issuance of Sitio OpCo Partnership Units and shares of Class C Common Stock and the terms by which such Sitio OpCo Partnership Units and shares of Class C Common Stock may be redeemed or exchanged for shares of Class A Common Stock, is incorporated into this Item 3.02 by reference.

In connection with the receipt of the Sitio OpCo Partnership Units and shares of Class C Common Stock described in the Introductory Note, the DPM Holders assigned their right to receive 0.5% of the Merger Consideration to the Company’s executive officers, representing 309,527 Sitio OpCo Partnership Units and 309,527 shares of Class C Common Stock collectively (the “Restricted Securities”), which are subject to certain transfer restrictions and forfeiture if certain conditions are not satisfied. In connection with the assignment of the right to receive the Restricted Securities, the Company and Sitio OpCo agreed that they would re-issue to the DPM Holders, on a one-for-one basis, Sitio OpCo Partnership Units and shares of Class C Common Stock to the extent Restricted Securities are forfeited (such rights, “Allocation Rights”). Sitio OpCo Partnership Units and shares of Class C Common Stock will be issued pursuant to Allocation Rights solely to the extent a corresponding forfeiture of Restricted Securities has occurred.

The issuance of Sitio OpCo Partnership Units, shares of Class C Common Stock and Allocation Rights to the DPM Holders and the Company’s executive officers were made in reliance on the exemption from registration requirements under the Securities Act, pursuant to Section 4(a)(2) thereof.

The description of the Restricted Securities provided in Item 5.02 hereto under the heading “Awards of Restricted Securities” is incorporated by reference into this Item 3.02.

 

Item 4.01

Change in Registrant’s Certifying Accountant.

Engagement of New Independent Registered Public Accounting Firm

In connection with the Closing of the Merger Transactions, the Company engaged KPMG LLP (“KPMG”) as its independent registered public accounting firm effective June 10, 2022. KPMG has served as the independent registered public accounting firm of Kimmeridge Mineral Fund, LP, Desert Peak’s predecessor, since 2020.

During the years ended December 31, 2021 and 2020 and through the date of filing this Current Report on Form 8-K, the Company has not, nor has anyone on the Company’s behalf, consulted with KPMG with respect to either (1) the application of accounting principles to a specified transaction, either completed or proposed, or the type of audit opinion that might be rendered on the Company’s consolidated financial statements, and neither a written report nor oral advice was provided to the Company that KPMG concluded was an important factor the Company considered in reaching a decision as to any accounting, auditing or financial reporting issue; or (2) any matter that was either the subject of a disagreement (as defined in Item 304(a)(1)(iv) of Regulation S-K and the related instructions to Item 304 of Regulation S-K) or a reportable event (as defined in Item 304(a)(1)(v) of Regulation S-K).

Dismissal of Independent Registered Public Accounting Firm

Concurrent with the Closing, Deloitte & Touche LLP (“Deloitte”), principal accountant, was dismissed as independent registered public accounting firm of the Company effective June 7, 2022. The decision to change the Company’s independent registered public accounting firm has been approved by the audit committee of the Board.

 

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The audit report of Deloitte on the consolidated balance sheets of the Company as of December 31, 2021 and 2020, and the related consolidated statements of operations, cash flows and shareholders’ equity for each of the three years in the period ended December 31, 2021 did not contain an adverse opinion or disclaimer of opinion, nor was it qualified or modified as to uncertainty, audit scope or accounting principles.

During the Company’s fiscal years ended December 31, 2021 and 2020 and through June 7, 2022 (including any subsequent interim period), there were no (i) disagreements (as defined in Item 304(a)(1)(iv) of Regulation S-K and the related instructions to Item 304 of Regulation S-K) between the Company and Deloitte on any matter of accounting principles or practices, financial statement disclosure, or auditing scope or procedures, which disagreements if not resolved to the satisfaction of Deloitte would have caused them to make reference in connection with their opinion on the subject matter of the disagreement, and (ii) no “reportable events” (as defined in Item 304(a)(1)(v) of Regulation S-K).

The Company has provided Deloitte a copy of the disclosure it is making in this Current Report on Form 8-K and has requested that Deloitte furnish it with a letter addressed to the SEC stating whether or not it agrees with the Company’s statements in this portion of Item 4.01 labeled “Dismissal of Independent Registered Public Accounting Firm.” A copy of the letter furnished by Deloitte in response to that request, dated June 10, 2022, is attached as Exhibit 16.1 to this Current Report on Form 8-K.

 

Item 5.01.

Changes in Control of Registrant.

The disclosure set forth in the Introductory Note and Items 1.01 and 5.02 is incorporated by reference into this Item 5.01.

 

Item 5.02.

Departure of Directors or Certain Officers; Election of Directors; Appointment of Certain Officers; Compensatory Arrangements of Certain Officers.

The disclosure set forth in Item 1.01 regarding the Director Designation Agreement is incorporated by reference into this Item 5.02. The description of the Director Designation Agreement is a summary only and is qualified in its entirety by reference to the full text of the Director Designation Agreement, a copy of which was filed with the SEC on January 12, 2022 as Exhibit 10.3 to Falcon’s Current Report on Form 8-K.

Directors

Effective as of the Closing Date, in connection with the Merger Transactions, William D. Anderson, Mark C. Henle, Adam M. Jenkins, Claire R. Harvey, Bryan C. Gunderson, Alan J. Hirshberg, Erik C. Belz and Steven R. Jones each resigned from the Board. The resignations of Messrs. Anderson, Henle, Jenkins, Gunderson, Hirshberg, Belz, Jones and Ms. Harvey were not a result of any disagreement with the Company. Effective as of the Closing Date, and pursuant to the Director Designation Agreement, the Board appointed Noam Lockshin, Morris R. Clark, Christopher L. Conoscenti, Alice E. Gould, Allen W. Li, Claire R. Harvey and Steven R. Jones to fill the newly created vacancies on the Board. Biographical information for these individuals is set forth in the Proxy Statement in the section entitled “Management after the Merger,” which is incorporated herein by reference.

Independence of Directors

The Board has determined that each of Mr. Lockshin, Mr. Clark, Ms. Harvey, Ms. Gould, Mr. Jones and Mr. Li are independent within the meaning of Nasdaq Rule 5605(a)(2), the NYSE listing rules following the Listing Transfer and the rules and regulations of the SEC.

Committees of the Board

As of and immediately following the Closing, the Board appointed the following directors to serve on the following committees:

 

   

Audit Committee: Morris R. Clark, Claire R. Harvey, Steven R. Jones

 

   

Compensation Committee: Alice E. Gould, Steven R. Jones, Allen W. Li

 

   

Corporate Governance and Nominating Committee: Noam Lockshin, Claire R. Harvey, Allen W. Li

 

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Mr. Clark was appointed chairman of the audit committee, Ms. Gould was appointed chairman of the compensation committee and Mr. Lockshin was appointed chairman of the corporate governance and nominating committee and lead independent director.

Executive Officers

On the Closing Date, in connection with the Merger Transactions, Bryan C. Gunderson resigned as the President and Chief Executive Officer of the Company, Matthew B. Ockwood resigned as the Chief Financial Officer of the Company, Stephen J. Pilatzke resigned as the Chief Accounting Officer of the Company, Jeffrey F. Brotman resigned as the Chief Legal Officer and Secretary of the Company, Michael J. Downs resigned as the Chief Operating Officer of the Company, Irene Deck resigned as the Vice President of Land of the Company and Austin Frey resigned as the Vice President of Reservoir Engineering of the Company.

In connection with the Merger Transactions, effective as of the Closing Date, the following individuals were appointed by the Board as executive officers of the Company:

 

Name

  

Position

Christopher L Conoscenti

   Chief Executive Officer

Carrie L. Osicka

   Chief Financial Officer

Britton L. James

   Executive Vice President of Land

Jarret J. Marcoux

   Executive Vice President of Engineering and Acquisitions

Brett S. Riesenfeld

   Executive Vice President, General Counsel and Secretary

Biographical information for each of the foregoing individuals is set forth in the Proxy Statement in the section entitled “Management after the Merger,” which is incorporated herein by reference.

Long Term Incentive Plan

At the Special Meeting held on June 3, 2022, the stockholders of the Company voted to approve the Sitio Royalties Corp. Long Term Incentive Plan (as amended from time to time, the “Incentive Plan”). The Incentive Plan provides for the grant of stock options, stock appreciation rights, restricted stock, restricted stock units, stock awards, dividend equivalents, other stock-based awards, cash awards and substitute awards. Subject to adjustment in accordance with the terms of the Incentive Plan, 8,384,083 shares of Class A Common Stock have been reserved for issuance pursuant to awards under the Incentive Plan. If an award under the Incentive Plan is forfeited, settled for cash or expires without the actual delivery of shares, any shares subject to such award will again be available for new awards under the Incentive Plan. The Incentive Plan will be administered by the Board’s compensation committee or the Board, as applicable.

The foregoing description of the Incentive Plan is a summary only and is subject to, and qualified in its entirety by reference to, the Incentive Plan, a copy of which is filed as Exhibit 10.4 to this Current Report on Form 8-K and is incorporated in this Item 5.02 by reference.

Awards of Restricted Securities

The disclosure set forth in Item 3.02, in so far as it relates to the Restricted Securities received by the Company’s executive officers, is incorporated into this Item 3.02 by reference.

Effective June 6, 2022 (the “Effective Date”), pursuant to an Assignment and Allocation Agreement entered into by and between the DPM Holders, Desert Peak, the Company, Sitio OpCo and each of the Company’s executive officers, substantially in the form attached hereto as Exhibit 10.5 to this Current Report on Form 8-K (the “Form Assignment and Allocation Agreement”), such executive officers received the following Restricted Securities: (i) Mr. Conoscenti: 92,858 Sitio OpCo Partnership Units and 92,858 shares of Class C Common Stock, (ii) Ms. Osicka: 60,186 Sitio OpCo Partnership Units and 60,186 shares of Class C Common Stock, (iii) Mr. James: 52,161 Sitio OpCo Partnership Units and 52,161 shares of Class C Common Stock, (iv) Mr. Marcoux: 52,161 Sitio OpCo Partnership Units and 52,161 shares of Class C Common Stock and (v) Mr. Riesenfeld: 52,161 Sitio OpCo Partnership Units and 52,161 shares of Class C Common Stock.

 

9


The Restricted Securities will vest in equal installments on the first four anniversaries of the Effective Date, so long as the executive officer remains continuously employed through each vesting date. Vesting of the Restricted Securities will accelerate in full upon a termination of an executive officer’s employment without cause, due to death or disability or, following a change in control, for good reason.

The foregoing description of the Restricted Securities is a summary only and is subject to, and qualified in its entirety by reference to, the Form Assignment and Allocation Agreement, a copy of which is filed as Exhibit 10.5 to this Current Report on Form 8-K and is incorporated in this Item 5.02 by reference.

Severance Plan

The Company adopted the Sitio Royalties Corp. Severance Plan, effective June 7, 2022 (as amended from time to time, the “Severance Plan”), which provides certain severance or change in control payments and benefits to our executive officers and certain other individuals who are selected for participation by Board’s compensation committee or the Board, as applicable, upon a qualifying termination (including a termination without cause, due to death or disability or for good reason) that relates to a change in control or otherwise.

The foregoing description of the Severance Plan is a summary only and is subject to, and qualified in its entirety by reference to, the Severance Plan, a copy of which is filed as Exhibit 10.6 to this Current Report on Form 8-K and is incorporated in this Item 5.02 by reference.

Indemnification of Directors and Officers

As of the Closing Date, the Company has entered into indemnification agreements with each of its directors and officers. These agreements require the Company to indemnify these individuals to the fullest extent permitted under Delaware law against liabilities that may arise by reason of their service to the Company, and to advance expenses incurred as a result of any proceeding against them as to which they could be indemnified.

The foregoing description of the indemnification agreements is a summary only and is subject to, and qualified in its entirety by reference to, the form of indemnification agreement, a copy of which is filed as Exhibit 10.7 to this Current Report on Form 8-K, is incorporated herein by reference and is substantially similar to the indemnification agreements entered into with each of the Company’s directors and officers.

 

Item 7.01.

Regulation FD Disclosure

On June 7, 2022, the Company issued a press release announcing the Closing of the Merger Transactions, a copy of which is furnished as Exhibit 99.1 and is incorporated herein by reference.

On June 7, 2022, the Company posted a new investor presentation to its website www.sitio.com. A copy of the investor presentation is furnished as Exhibit 99.2 to this Current Report on Form 8-K and incorporated into this Item 7.01 by reference. The information contained on the Company’s website shall not be deemed part of this report.

In accordance with General Instruction B.2 of Form 8-K, the information contained in this Current Report on Form 8-K under Item 7.01 and set forth in the attached Exhibits 99.1 and 99.2 is deemed to be “furnished” solely pursuant to Item 7.01 of Form 8-K and shall not be deemed to be “filed” for purposes of Section 18 of the Exchange Act or otherwise subject to the liabilities of that section, nor shall such information be deemed incorporated by reference into any filing under the Securities Act, or the Exchange Act, except as expressly set forth by specific reference in such a filing.

 

Item 8.01

Other Events.

In connection with Closing, the Company is providing certain disclosures regarding Desert Peak and its business prior to the closing of the Merger. Such disclosures are set forth in the Proxy Statement in the sections entitled “Risk Factors—Risk Factors Related to Desert Peak” and “Information about Desert Peak,” which are incorporated herein by reference and attached hereto as Exhibits 99.7 and 99.8.

 

10


Item 9.01.

Financial Statements and Exhibits.

(a)    Financial statements of businesses acquired.

 

   

Audited combined and consolidated financial statements of Kimmeridge Mineral Fund, L.P. (the “Partnership”), Desert Peak’s predecessor, as of December 31, 2021 and 2020 and for each of the three years ended December 31, 2021, 2020 and 2019, and the related notes to the combined and consolidated financial statements, included in the Proxy Statement, beginning on page F-5, attached as Exhibit 99.3 hereto;

 

   

Unaudited combined and consolidated financial statements of the Partnership as of March 31, 2022 and December 31, 2021 and for the three months ended March 31, 2022 and 2021, and the related notes to the combined and consolidated financial statements, attached as Exhibit 99.4 hereto; and

 

   

Management’s Discussion and Analysis of Financial Condition and Results of Operations of the Partnership for the years ended December 31, 2021, 2020 and 2019 and for the three months ended March 31, 2022 and 2021, attached as Exhibit 99.5 hereto.

(b)    Pro forma financial information.

The following unaudited pro forma condensed combined financial information of the Company, giving effect to the Merger Transactions, attached as Exhibit 99.6 hereto, are incorporated herein by reference:

 

   

Unaudited Pro Forma Condensed Consolidated Combined Balance Sheet as of March 31, 2022;

 

   

Unaudited Pro Forma Condensed Consolidated Combined Statements of Operations for the year ended December 31, 2021 and three months ended March 31, 2022; and

 

   

Notes to the Unaudited Pro Forma Condensed Consolidated Combined Financial Statements.

(d)    Exhibits.

 

Exhibit
No.

  

Description

  2.1    Agreement and Plan of Merger, dated as of January 11, 2022, by and among Falcon Minerals Corporation, Falcon Minerals Operating Partnership, LP, Ferrari Merger Sub A LLC, and DPM HoldCo, LLC (incorporated by reference to Exhibit 2.1 to the Registrant’s Current Report on Form 8-K filed on January 12, 2022).
10.1    Director Designation Agreement, dated as of January 11, 2022, by and among Falcon Minerals Corporation, Chambers DPM HoldCo, LLC, KMF DPM HoldCo, LLC, Source Energy Leasehold, LP, Permian Mineral Acquisitions, LP, Rock Ridge Royalty Company, LLC and Royal Resources L.P. (incorporated by reference to Exhibit 10.3 to the Registrant’s Current Report on Form 8-K filed on January 12, 2022).
10.2    Registration Rights Agreement, dated as of January 11, 2022, by and among Falcon Minerals Corporation, Chambers DPM HoldCo, LLC, KMF DPM HoldCo, LLC, Source Energy Leasehold, LP, Permian Mineral Acquisitions, LP, Rock Ridge Royalty Company, LLC and Royal Resources L.P. (incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed on January 12, 2022).
10.3    Second Amended and Restated Agreement of Limited Partnership of Sitio Royalties Operating Partnership, L.P., dated as of June 7, 2022.
10.4    Sitio Royalties Corp. Long Term Incentive Plan.
10.5    Form of DPM HoldCo, LLC Assignment and Allocation Agreement.
10.6    Sitio Royalties Corp. Severance Plan.
10.7    Form of Indemnification Agreement.

 

11


Exhibit
No.

  

Description

10.8    Second Amended and Restated Credit Agreement, by and among Sitio Royalties Operating Partnership, LP, as borrower, KMF Land, LLC, Bank of America, N.A., as the administrative agent and issuing bank, the lenders party thereto and other financial institutions from time to time party thereto.
16.1    Letter to the Securities and Exchange Commission from Deloitte & Touche LLP, dated as of June 10, 2022.
23.1    Consent of KPMG LLP.
23.2    Consent of Report of Cawley, Gillespie & Associates, Inc.
99.1    Press Release of Sitio Royalties Corp., dated June 7, 2022.
99.2    Investor Presentation dated June 7, 2022.
99.3    Historical audited financial statements of Kimmeridge Mineral Fund, L.P. as of December 31, 2020 and 2019 and for the years ended December 31, 2021, 2020 and 2019.
99.4    Historical unaudited combined and consolidated financial statements of Kimmeridge Mineral Fund, L.P. as of March 31, 2022 and December 31, 2021 and for the three months ended March 31, 2022 and 2021.
99.5    Management’s Discussion and Analysis of Financial Condition and Results of Operations of Kimmeridge Mineral Fund, L.P. for the years ended December 31, 2021, 2020 and 2019 and for the three months ended March 31, 2022 and 2021.
99.6    Unaudited pro forma condensed consolidated combined financial statements of Sitio Royalties Corp.
99.7    Risk Factors—Risk Factors Related to Desert Peak
99.8    Information about Desert Peak
99.9    Report of Cawley, Gillespie & Associates, Inc. as of December 31, 2021 (Desert Peak Minerals) (incorporated by reference to Annex H of the Company’s Proxy Statement).
99.10    Report of Cawley, Gillespie & Associates, Inc. as of December 31, 2020 (Kimmeridge Mineral Fund, LP) (incorporated by reference to Annex G of the Company’s Proxy Statement).
104    Cover Page Interactive Data File (embedded within the Inline XBRL document).

 

12


SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

 

    SITIO ROYALTIES CORP.
Date: June 10, 2022      
    By:  

/s/ Brett S. Riesenfeld

      Brett S. Riesenfeld
      General Counsel and Secretary

 

13

Exhibit 10.3

SECOND AMENDED AND RESTATED

AGREEMENT OF LIMITED PARTNERSHIP

OF

SITIO ROYALTIES OPERATING PARTNERSHIP, LP.

Dated as of June 7, 2022

 

 

THE UNITS REPRESENTED BY THIS SECOND AMENDED AND RESTATED AGREEMENT OF LIMITED PARTNERSHIP HAVE NOT BEEN REGISTERED UNDER THE UNITED STATES SECURITIES ACT OF 1933, AS AMENDED, OR UNDER ANY OTHER APPLICABLE SECURITIES LAWS. SUCH UNITS MAY NOT BE SOLD, ASSIGNED, PLEDGED OR OTHERWISE DISPOSED OF AT ANY TIME WITHOUT EFFECTIVE REGISTRATION UNDER SUCH ACT AND LAWS OR EXEMPTION THEREFROM, AND COMPLIANCE WITH THE OTHER SUBSTANTIAL RESTRICTIONS ON TRANSFERABILITY SET FORTH HEREIN.


Table of Contents

 

ARTICLE I DEFINITIONS

     2  

ARTICLE II ORGANIZATIONAL MATTERS

     15  

Section 2.01

  Formation of Partnership      15  

Section 2.02

  Second Amended and Restated Limited Partnership Agreement      15  

Section 2.03

  Name      15  

Section 2.04

  Purpose      15  

Section 2.05

  Principal Office; Registered Office      16  

Section 2.06

  Term      16  

Section 2.07

  No Joint Venture      16  

ARTICLE III PARTNERS; UNITS; CAPITALIZATION

     16  

Section 3.01

  Partners      16  

Section 3.02

  Units      17  

Section 3.03

  Contribution Agreement and DPM Merger Agreement      17  

Section 3.04

  Authorization and Issuance of Additional Units      17  

Section 3.05

  Repurchases or Redemptions      20  

Section 3.06

  Certificates Representing Units; Lost, Stolen or Destroyed Certificates; Registration and Transfer of Units      21  

Section 3.07

  Negative Capital Accounts      21  

Section 3.08

  No Withdrawal      21  

Section 3.09

  Loans From Partners      21  

Section 3.10

  Tax Treatment of Corporate Stock Option Plans and Equity Plans      21  

Section 3.11

  Dividend Reinvestment Plan, Cash Option Purchase Plan, Stock Incentive Plan or Other Plan      23  

Section 3.12

  Deemed Capital Contributions      23  

ARTICLE IV DISTRIBUTIONS

     24  

Section 4.01

  Distributions      24  

Section 4.02

  Restricted Distributions      24  

ARTICLE V CAPITAL ACCOUNTS; ALLOCATIONS; TAX MATTERS

     24  

Section 5.01

  Capital Accounts      24  

Section 5.02

  Book Allocations      26  

Section 5.03

  Regulatory and Special Allocations      26  

Section 5.04

  Tax Allocations      28  

Section 5.05

  Withholding; Indemnification and Reimbursement for Payments on Behalf of a Partner      30  

Section 5.06

  DPM Merger Agreement      31  

 

i


ARTICLE VI MANAGEMENT

     31  

Section 6.01

  Authority of General Partner      31  

Section 6.02

  Actions of the General Partner      32  

Section 6.03

  Transfer and Withdrawal of General Partner      32  

Section 6.04

  Transactions Between Partnership and General Partner      33  

Section 6.05

  Reimbursement for Expenses      33  

Section 6.06

  Delegation of Authority      34  

Section 6.07

  Limitation of Liability of the General Partner      34  

Section 6.08

  Investment Company Act      35  

Section 6.09

  Outside Activities of the Corporation and the General Partner      35  

Section 6.10

  Standard of Care      35  

ARTICLE VII RIGHTS AND OBLIGATIONS OF PARTNERS

     36  

Section 7.01

  Limitation of Liability and Duties of Partners; Investment Opportunities      36  

Section 7.02

  Lack of Authority      37  

Section 7.03

  No Right of Partition      37  

Section 7.04

  Indemnification      37  

Section 7.05

  Limited Partners’ Right to Act      38  

Section 7.06

  Inspection Rights      39  

ARTICLE VIII BOOKS, RECORDS, ACCOUNTING AND REPORTS

     39  

Section 8.01

  Records and Accounting      39  

Section 8.02

  Fiscal Year      39  

Section 8.03

  Reports      40  

ARTICLE IX TAX MATTERS

     40  

Section 9.01

  Preparation of Tax Returns      40  

Section 9.02

  Tax Elections      40  

Section 9.03

  Tax Controversies      41  

ARTICLE X RESTRICTIONS ON TRANSFER OF UNITS

     41  

Section 10.01

  Transfers by Partners      41  

Section 10.02

  Permitted Transfers      41  

Section 10.03

  Restricted Units Legend      42  

Section 10.04

  Transfer      43  

Section 10.05

  Assignee’s Rights      43  

Section 10.06

  Assignor’s Rights and Obligations      43  

Section 10.07

  Overriding Provisions      44  

ARTICLE XI REDEMPTION AND EXCHANGE RIGHTS

     45  

Section 11.01

  Redemption Right of a Limited Partner      45  

ARTICLE XII ADMISSION OF LIMITED PARTNERS

     51  

Section 12.01

  Substituted Limited Partners      51  

Section 12.02

  Additional Limited Partners      51  

ARTICLE XIII WITHDRAWAL AND RESIGNATION; TERMINATION OF RIGHTS

     51  

Section 13.01

  Withdrawal and Resignation of Limited Partners      51  

 

ii


ARTICLE XIV DISSOLUTION AND LIQUIDATION

     51  

Section 14.01

  Dissolution      51  

Section 14.02

  Liquidation and Termination      52  

Section 14.03

  Deferment; Distribution in Kind      53  

Section 14.04

  Cancellation of Certificate      53  

Section 14.05

  Reasonable Time for Winding Up      53  

Section 14.06

  Return of Capital      53  

ARTICLE XV VALUATION

     53  

Section 15.01

  Determination      53  

Section 15.02

  Dispute Resolution      54  

ARTICLE XVI GENERAL PROVISIONS

     54  

Section 16.01

  Power of Attorney      54  

Section 16.02

  Confidentiality      55  

Section 16.03

  Amendments      55  

Section 16.04

  Title to Partnership Assets      56  

Section 16.05

  Addresses and Notices      56  

Section 16.06

  Binding Effect; Intended Beneficiaries      56  

Section 16.07

  Creditors      56  

Section 16.08

  Waiver      57  

Section 16.09

  Counterparts      57  

Section 16.10

  Applicable Law      57  

Section 16.11

  Severability      57  

Section 16.12

  Further Action      57  

Section 16.13

  Delivery by Electronic Transmission      57  

Section 16.14

  Right of Offset      58  

Section 16.15

  Effectiveness      58  

Section 16.16

  Entire Agreement      58  

Section 16.17

  Remedies      58  

Section 16.18

  Descriptive Headings; Interpretation      58  

Schedules

Schedule 1 –Schedule of Limited Partners

Exhibits

Exhibit A – Form of Joinder Agreement

 

iii


SECOND AMENDED AND RESTATED

AGREEMENT OF LIMITED PARTNERSHIP

SITIO ROYALTIES OPERATING PARTNERSHIP, LP

This SECOND AMENDED AND RESTATED AGREEMENT OF LIMITED PARTNERSHIP (this “Agreement”) of Sitio Royalties Operating Partnership, LP, a Delaware limited partnership (the “Partnership”), dated as of June 7, 2022, is adopted, executed and agreed to by and among Sitio Royalties GP, LLC, a Delaware limited liability company, as the sole general partner of the Partnership, and each of the Limited Partners (as defined herein) set forth on the signature pages hereto.

WHEREAS, the Partnership was formed as a limited partnership pursuant to and in accordance with the Delaware Act (as defined herein) by filing a Certificate of Limited Partnership of the Partnership (the “Certificate”) with the Secretary of State of the State of Delaware on May 31, 2018;

WHEREAS, the General Partner, as the sole general partner of the Partnership, entered into an Agreement of Limited Partnership of the Partnership, dated as of May 31, 2018 (as amended, restated, amended and restated, supplemented or otherwise modified, together with all schedules, exhibits and annexes thereto, the “Initial Limited Partnership Agreement”), with Osprey Minerals Corporation, a Delaware corporation and formerly named Falcon Energy Acquisition Corp. (the “Corporation”), as the sole limited partner of the Partnership;

WHEREAS, the Corporation entered into a Contribution Agreement, dated as of June 3, 2018 (the “Contribution Agreement”), by and among Royal Resources L.P., a Delaware limited partnership (“Royal LP”), Royal Resources GP L.L.C., a Delaware limited liability company (“Royal GP”, and collectively with Royal LP, “Royal”), the Corporation, and the other parties thereto (such other parties collectively, the “Royal Contributors” and each a “Royal Contributor”);

WHEREAS, pursuant to the Contribution Agreement, at the Royal Closing, the Corporation contributed to the Partnership, as a capital contribution, cash as set forth in the Contribution Agreement in exchange for the issuance by the Partnership to the Corporation of (a) a number of Common Units (as defined below) equal to the number of shares of Class A Common Stock (as defined below) outstanding at the Royal Closing after the consummation of the Royal Transactions (as defined below) and (b) a number of Warrants (as defined below) equal to the number of Corporation Warrants (as defined below) outstanding at the Royal Closing after the consummation of the Royal Transactions (such contribution, the “Corporation Contribution”);

WHEREAS, pursuant to the Contribution Agreement, at the Royal Closing, the Royal Contributors contributed certain equity interests to the Partnership in exchange for a combination of Common Units and cash as set forth in the Contribution Agreement (such contribution, the “Royal Contribution”);

WHEREAS, in connection with the Contribution Agreement, the Initial Limited Partnership Agreement was amended and restated on August 23, 2018 by the parties thereto (as amended, restated, amended and restated, supplemented or otherwise modified from time to time to but excluding the date hereof, together with all schedules, exhibits and annexes thereto, the “Prior Limited Partnership Agreement”);

 

1


WHEREAS, the Corporation, the Partnership, Ferrari Merger Sub A LLC, a Delaware limited liability company and wholly owned subsidiary of the Partnership (“DPM Merger Sub”), and DPM HoldCo, LLC, a Delaware limited liability company (“DPM”), entered into an Agreement and Plan of Merger, dated as of January 11, 2022 (the “DPM Merger Agreement”), pursuant to which DPM Merger Sub shall merge with and into DPM with DPM being the surviving entity and a wholly owned subsidiary of the Partnership; and

WHEREAS, the parties are entering into this Agreement to amend and restate the Prior Limited Partnership Agreement effective as of the Effective Time, at which time the Prior Limited Partnership Agreement shall be superseded entirely by this Agreement.

NOW, THEREFORE, in consideration of the mutual covenants, rights and obligations set forth herein and other good and valuable consideration, the receipt and sufficiency of which each Partner (as defined herein) hereby acknowledges and confesses, the parties hereto hereby agree as follows:

ARTICLE I

DEFINITIONS

The following definitions shall be applied to the terms used in this Agreement for all purposes, unless otherwise clearly indicated to the contrary.

Additional Limited Partner has the meaning set forth in Section 12.02.

Adjusted Capital Account Deficit means, with respect to the Capital Account of any Partner as of the end of any Taxable Year or Fiscal Period, the amount by which the balance in such Capital Account is less than zero. For this purpose, such Partner’s Capital Account balance shall be:

(a) reduced for any items described in Treasury Regulations Section 1.704-1(b)(2)(ii)(d)(4), (5), and (6); and

(b) increased for any amount such Partner is obligated to contribute or is treated as being obligated to contribute to the Partnership pursuant to Treasury Regulations Section 1.704-1(b)(2)(ii)(c) (relating to partner liabilities to a partnership) or 1.704-2(g)(1) and 1.704-2(i)(5) (relating to minimum gain).

Admission Date has the meaning set forth in Section 10.06.

Affiliate (and, with a correlative meaning, “Affiliated”) means, with respect to a specified Person, each other Person that directly, or indirectly through one or more intermediaries, controls or is controlled by, or is under common control with, the Person specified. As used in this definition and the definition of Majority Partners, “control” (including with correlative meanings, “controlled by” and “under common control with”) means possession, directly or indirectly, of power to direct or cause the direction of management or policies (whether through ownership of voting securities or by contract or other agreement).

 

2


Agreement has the meaning set forth in the preamble to this Agreement.

Appraisers has the meaning set forth in Section 15.02.

Assignee means a Person to whom a Limited Partner Interest has been transferred but who has not become a Limited Partner pursuant to Article XII.

Average VWAP” per share of Class A Common Stock over a certain period shall mean the arithmetic average of the VWAP per share of Class A Common Stock for each Trading Day in such period.

Base Rate means, on any date, a variable rate per annum equal to the rate of interest most recently published by The Wall Street Journal as the “prime rate” at large U.S. money center banks.

Blackstone Parties means the Royal Contributors, Royal, Rock Ridge Royalty Company LLC, Blackstone Management Partners, L.L.C. and any of their respective Affiliates.

Book Value means, with respect to any Partnership property, the Partnership’s adjusted basis for U.S. federal income tax purposes, adjusted from time to time to reflect the adjustments required or permitted by Treasury Regulations Sections 1.704-1(b)(2)(iv)(d)-(g) and 1.704-1(b)(2)(iv)(s); provided, that if any noncompensatory options (including the Warrants) are outstanding upon the occurrence of any adjustment described herein, the Partnership shall adjust the Book Values of its properties in accordance with Treasury Regulations Sections 1.704-1(b)(2)(iv)(f)(1) and 1.704-1(b)(2)(iv)(h)(2).

Business Day means any day other than a Saturday or a Sunday or a day on which banks located in New York City, New York generally are authorized or required by Law to close.

Call Right” has the meaning set forth in Section 11.01(m).

Capital Account means the capital account maintained for a Partner in accordance with Section 5.01.

Capital Contribution means, with respect to any Partner, the amount of any cash, cash equivalents, promissory obligations or the Fair Market Value of other property that such Partner contributes (or is deemed to contribute) to the Partnership pursuant to Article III hereof.

Cash Election” means an election by the Company to redeem Units for cash pursuant to Section 11.01(d) or an election by the Corporation (or such designated member(s) of the Corporation Holdings Group) to purchase Units for cash pursuant to an exercise of its Call Right set forth in Section 11.01(m).

Cash Election Amount” means with respect to a particular Redemption for which a Cash Election has been made, (a) other than in the case of clause (b), if the Class A Common Stock trades on a securities exchange or automated or electronic quotation system, an amount of cash equal to the product of (i) the number of shares of Class A Common Stock that would have been

 

3


received in such Redemption if a Cash Election had not been made and (ii) the Average VWAP for the five (5) consecutive full Trading Days ending on and including the last full Trading Day immediately prior to the Redemption Notice Date, subject to appropriate and equitable adjustment for any stock splits, reverse splits, stock dividends or similar events affecting the Class A Common Stock; (b) if the Cash Election is made in respect of a Redemption Notice issued by a Redeeming Partner in connection with a Public Offering, an amount of cash equal to the product of (i) the number of shares of Class A Common Stock that would have been received in such Redemption if a Cash Election had not been made and (ii) the price per share of Class A Common Stock sold to the public in such Public Offering (reduced by the amount of any Discount associated with such share of Class A Common Stock), and (c) if the Class A Common Stock no longer trades on a securities exchange or automated or electronic quotation system, an amount of cash equal to the product of (i) the number of shares of Class A Common Stock that would have been received in such Redemption if a Cash Election had not been made and (ii) the fair market value of one share of Class A Common Stock, as determined by the General Partner in good faith, that would be obtained in an arms’ length transaction for cash between an informed and willing buyer and an informed and willing seller, neither of whom is under any compulsion to buy or sell, and without regard to the particular circumstances of the buyer or seller and without any discounts for liquidity or minority discount.

Certificate has the meaning set forth in the recitals to this Agreement.

Change of Control Exchange Date” has the meaning set forth in Section 11.01(p).

Change of Control Transaction means (a) a sale of all or substantially all of the Partnership’s assets determined on a consolidated basis, (b) a sale of a majority of the Partnership’s outstanding Units (other than (i) to the Corporation or (ii) in connection with a Redemption or Call Right in accordance with Article XI) or (c) a sale of a majority of the outstanding voting securities of any Material Subsidiary of the Partnership; in any such case, whether by merger, recapitalization, consolidation, reorganization, combination or otherwise; provided, however, that neither (w) a transaction solely between the Partnership or any of its wholly-owned Subsidiaries, on the one hand, and the Partnership or any of its wholly-owned Subsidiaries, on the other hand, nor (x) a transaction solely for the purpose of changing the jurisdiction of domicile of the Partnership, nor (y) a transaction solely for the purpose of changing the form of entity of the Partnership, nor (z) a sale of a majority of the outstanding shares of Class A Common Stock, whether by merger, recapitalization, consolidation, reorganization, combination or otherwise, shall in each case of clauses (w), (x), (y) and (z) constitute a Change of Control Transaction.

Class A Common Stock means (a) the Class A Common Stock, par value $0.0001 per share, of the Corporation or (b) following any consolidation, merger, reclassification or other similar event involving the Corporation, any shares or other securities of the Corporation or any other Person or cash or other property that become payable in consideration for the Class A Common Stock or into which the Class A Common Stock are exchanged or converted as a result of such consolidation, merger, reclassification or other similar event.

Class C Common Stock means (a) the Class C Common Stock, par value $0.0001 per share, of the Corporation or (b) following any consolidation, merger, reclassification or other similar event involving the Corporation, any shares or other securities of the Corporation or any other Person or cash or other property that become payable in consideration for the Class C Common Stock or into which the Class C Common Stock are exchanged or converted as a result of such consolidation, merger, reclassification or other similar event

 

4


Code means the United States Internal Revenue Code of 1986, as amended.

Common Stock means all classes and series of common stock of the Corporation, including the Class A Common Stock and the Class C Common Stock.

Common Unit means a Unit representing a fractional part of the Limited Partner Interests of the Limited Partners and having the rights and obligations specified with respect to the Common Units in this Agreement.

Contribution Agreement has the meaning set forth in the recitals to this Agreement.

Corporate Board means the Board of Directors of the Corporation.

Corporate Charter means the Third Amended and Restated Certificate of Incorporation of the Corporation, which is effective substantially concurrently with the effectiveness of this Agreement, as it may be amended, restated, supplemented or otherwise modified from time to time.

Corporation has the meaning set forth in the recitals to this Agreement, together with its successors and assigns.

Corporation Warrants means the “Buyer Warrants” as defined in Section 1.1 of the Contribution Agreement.

Credit Agreement means any senior credit facility or obligation of the Partnership or any of its Subsidiaries, as borrower, as may be subsequently amended, restated, supplemented or otherwise modified from time to time and including any one or more refinancings or replacements thereof, in whole or in part, with any other debt facility or debt obligation).

Corporate Tax Liabilities” means any U.S. federal, state and local and non-U.S. tax obligations (including any Partnership Level Taxes for which the Corporation Holdings Group is liable hereunder) owed by the Corporation Holdings Group (other than any obligations to remit withholdings withheld from payments to third parties).

Corporation Holdings Group” means the Corporation and each other direct or indirect wholly-owned Subsidiary of the Corporation (other than the Partnership and its Subsidiaries).

Delaware Act means the Delaware Revised Uniform Limited Partnership Act, 6 Del.L. § 17-101, et seq., as it may be amended from time to time, and any successor thereto.

Depletable Property means each separate oil and gas property as defined in Code Section 614.

 

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Depreciation means, for each Taxable Year or other Fiscal Period, an amount equal to the depreciation, amortization or other cost recovery deduction (excluding depletion) allowable for U.S. federal income tax purposes with respect to property for such Taxable Year or other Fiscal Period, except that (a) with respect to any such property the Book Value of which differs from its adjusted tax basis for U.S. federal income tax purposes and which difference is being eliminated by use of the “remedial method” pursuant to Treasury Regulations Section 1.704-3(d), Depreciation for such Taxable Year or other Fiscal Period shall be the amount of book basis recovered for such Taxable Year or other Fiscal Period under the rules prescribed by Treasury Regulations Section 1.704-3(d)(2), and (b) with respect to any other such property the Book Value of which differs from its adjusted tax basis at the beginning of such Taxable Year or other Fiscal Period, Depreciation for such Taxable Year or other Fiscal Period shall be an amount which bears the same ratio to such beginning Book Value as the U.S. federal income tax depreciation, amortization, or other cost recovery deduction for such Taxable Year or other Fiscal Period bears to such beginning adjusted tax basis; provided, however, that if the adjusted tax basis of any property at the beginning of such Taxable Year or other Fiscal Period is zero dollars ($0.00), Depreciation with respect to such property shall be determined with reference to such beginning Book Value using any reasonable method selected by the General Partner.

Discount has the meaning set forth in Section 11.01(i).

Distributable Cash means, as of any relevant date on which a determination is being made by the General Partner regarding a potential distribution pursuant to Section 4.01(a), the amount of cash that could be distributed by the Partnership for such purposes in accordance with the Credit Agreement (and without otherwise violating any applicable provisions of the Credit Agreement or any other debt financing of the Partnership or its Subsidiaries).

Distribution (and, with a correlative meaning, “Distribute”) means each distribution made by the Partnership to a Limited Partner with respect to such Limited Partner’s Units, whether in cash, property or securities of the Partnership and whether by liquidating distribution or otherwise; provided, however, that none of the following shall be a Distribution: (a) any recapitalization that does not result in the distribution of cash or property to Limited Partners or any exchange of securities of the Partnership, and any subdivision (by Unit split or otherwise) or any combination (by reverse Unit split or otherwise) of any outstanding Units, (b) any other payment made by the Partnership to a Limited Partner in redemption of all or a portion of such Limited Partner’s Units or (c) any amounts payable pursuant to Section 6.05.

DPM has the meaning set forth in the recitals to this Agreement.

DPM Closing” means the “Closing” as defined in Section 1.2 of the DPM Merger Agreement.

DPM Holders” means KMF DPM HoldCo, LLC, Chambers DPM HoldCo, LLC, Rock Ridge Royalty Company LLC, Source Energy Leasehold, LP and Permian Mineral Acquisitions, LP.

DPM Merger” means the “Merger” as defined in the recitals of the DPM Merger Agreement.

DPM Merger Agreement has the meaning set forth in the recitals to this Agreement.

 

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DPM Merger Sub has the meaning set forth in the recitals to this Agreement.

DPM Registration Rights Agreement means that certain Registration Rights Agreement, dated as of January 11, 2022, by and among the Corporation, Royal LP and the DPM Holders.

Effective Time has the meaning set forth in Section 16.15.

Equity Plan means any stock or equity purchase plan, restricted stock or equity plan or other similar equity compensation plan now or hereafter adopted by the Partnership or the Corporation.

Equity Securities means (a) with respect to the Partnership or any of its Subsidiaries, (i) Units or other equity interests in the Partnership or any Subsidiary of the Partnership (including other classes or groups thereof having such relative rights, powers and duties as may from time to time be established by the General Partner pursuant to the provisions of this Agreement, including rights, powers and/or duties senior to existing classes and groups of Units and other equity interests in the Partnership or any Subsidiary of the Partnership), (ii) obligations, evidences of indebtedness or other securities or interests convertible or exchangeable into Units or other equity interests in the Partnership or any Subsidiary of the Partnership, and (iii) warrants, options or other rights to purchase or otherwise acquire Units or other equity interests in the Partnership or any Subsidiary of the Partnership and (b) with respect to the Corporation, any and all shares, interests, participation or other equivalents (however designated) of corporate stock, including all common stock and preferred stock, or warrants, options or other rights to acquire any of the foregoing, including any debt instrument convertible or exchangeable into any of the foregoing.

Event of Withdrawal means the expulsion, bankruptcy or dissolution of a Partner or the occurrence of any other event that terminates the continued partnership of a Partner in the Partnership. “Event of Withdrawal” shall not include an event that does not terminate the existence of such Partner under applicable state law (or, in the case of a trust that is a Partner, does not terminate the trusteeship of the fiduciaries under such trust with respect to all the Limited Partner Interests of such trust that is a Limited Partner).

Exchange Act means the Securities Exchange Act of 1934, as amended.

Fair Market Value means, with respect to any asset, its fair market value determined according to Article XV.

Falcon OpCo Contribution” has the meaning set forth in Section 5.06(a).

Fiscal Period means any interim accounting period within a Taxable Year established by the Partnership and which is permitted or required by Section 706 of the Code.

Fiscal Year means the Partnership’s annual accounting period established pursuant to Section 8.02.

General Partner means Sitio Royalties GP, LLC (formerly named Falcon Minerals GP, LLC), a Delaware limited liability company, and its successors and permitted assigns as general partner of the Partnership. The General Partner, in its capacity as such, has no obligation to make Capital Contributions or right to receive Distributions under this Agreement.

 

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General Partner Change of Control shall be deemed to have occurred if or upon:

(a) both the stockholders of the Corporation and the Corporate Board approve, in accordance with the Corporation’s certificate of incorporation and applicable law, the sale, lease or transfer, in one or a series of related transactions, of all or substantially all of the Corporation’s assets (determined on a consolidated basis), including a sale of all of the equity interests in the Partnership, to any Person or group (as such term is used in Section 13(d)(3) of the Exchange Act), other than to any directly or indirectly wholly owned Subsidiary of the Corporation, and such sale, lease or transfer is consummated;

(b) both the stockholders of the Corporation and the Corporate Board approve, in accordance with the Corporation’s certificate of incorporation and applicable law, a merger or consolidation of the Corporation with any other Person, other than a merger or consolidation which would result in the Voting Securities of the Corporation outstanding immediately prior thereto continuing to represent (either by remaining outstanding or by being converted into Voting Securities of the surviving entity) at least 50.01% of the total voting power represented by the Voting Securities of the Corporation or such surviving entity outstanding immediately after such merger or consolidation, and such merger or consolidation is consummated; or

(c) the acquisition, directly or indirectly, by any Person or group (as such term is used in Section 13(d)(3) of the Exchange Act) (other than (i) a trustee or other fiduciary holding securities under an employee benefit plan of the Corporation, or (ii) a corporation or other entity owned, directly or indirectly, by all of the stockholders of the Corporation in substantially the same proportions as their ownership of stock of the Corporation) of beneficial ownership (as defined in Rule 13d-3 under the Exchange Act) of at least 50.01% of the aggregate voting power of the Voting Securities of the Corporation; provided, that the Corporate Board recommends or otherwise approves or determines that such acquisition is in the best interests of the Corporation and its stockholders.

General Partner Interest means the non-economic management interest of the General Partner in the Partnership (in its capacity as a general partner without reference to any Limited Partner Interest held by it) and includes any and all rights, powers and benefits to which the General Partner is entitled as provided in this Agreement, together with all obligations of the General Partner to comply with the terms and provisions of this Agreement. The General Partner Interest does not include any rights to Profits or Losses or any rights to receive Distributions from operations or upon the liquidation or winding-up of the Partnership.

Governmental Entity means (a) the United States of America, (b) any other sovereign nation, (c) any state, province, district, territory or other political subdivision of (a) or (b) of this definition, including any county, municipal or other local subdivision of the foregoing, or (d) any entity exercising executive, legislative, judicial, regulatory or administrative functions of government on behalf of (a), (b) or (c) of this definition.

 

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Indemnified Person has the meaning set forth in Section 7.04(a).

Independent Directors means the members of the Corporate Board who qualify as an independent director pursuant to applicable SEC Guidance and the rules of the stock exchange on which the Common Shares are traded.

Initial Limited Partnership Agreement has the meaning set forth in the recitals to this Agreement.

Investment Company Act means the U.S. Investment Company Act of 1940, as amended from time to time.

Joinder means a joinder to this Agreement, in form and substance substantially similar to Exhibit A to this Agreement.

Kimmeridge Parties” means KMF DPM HoldCo, LLC, Chambers DPM HoldCo, LLC and their respective Affiliates.

Law means all laws, statutes, ordinances, rules and regulations of any Governmental Entity, any foreign country and each state, commonwealth, city, county, municipality, regulatory body, agency or other political subdivision thereof.

Limited Partner means, as of any date of determination, (a) each of the partners named on the Schedule of Limited Partners and (b) any Person admitted to the Partnership as a Substituted Limited Partner or Additional Limited Partner in accordance with Article XII, but in each case only so long as such Person is shown on the Partnership’s books and records as the owner of one or more Units.

Limited Partner Interest means the interest of a Partner in Profits, Losses and Distributions.

Losses has the meaning set forth in Section 5.01(c).

Majority Partners means the Limited Partners (which may include the General Partner if it is also a Limited Partner) holding a majority of the Units then outstanding; provided that, if as of any date of determination, a majority of the Units are then held by the General Partner or any of its Affiliates controlled by the Corporation (including the Corporation Holdings Group), then “Majority Partners” shall mean the General Partner together with Partners holding a majority of the Units (excluding Units held by the General Partner and its controlled Affiliates including the Corporation Holdings Group) then outstanding.

Market Price means, with respect to a share of Class A Common Stock as of a specified date, the last sale price per share of Class A Common Stock, regular way, or if no such sale took place on such day, the average of the closing bid and asked prices per share of Class A Common Stock, regular way, in either case as reported in the principal consolidated transaction reporting system with respect to securities listed or admitted to trading on the Stock Exchange or, if the Class A Common Stock is not listed or admitted to trading on the Stock Exchange, as reported on the principal consolidated transaction reporting system with respect to securities listed on the principal

 

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national securities exchange on which the Class A Common Stock is listed or admitted to trading or, if the Class A Common Stock is not listed or admitted to trading on any national securities exchange, the last quoted price, or, if not so quoted, the average of the high bid and low asked prices in the over-the-counter market, as reported by the National Association of Securities Dealers, Inc. Automated Quotation System or, if such system is no longer in use, the principal other automated quotation system that may then be in use or, if the Class A Common Stock is not quoted by any such organization, the average of the closing bid and asked prices as furnished by a professional market maker making a market in the Class A Common Stock selected by the Corporate Board or, in the event that no trading price is available for the shares of Class A Common Stock, the fair market value of a share of Class A Common Stock, as determined in good faith by the Corporate Board.

Material Subsidiary means any direct or indirect Subsidiary of the Partnership that, as of any date of determination, represents more than (a) 50% of the consolidated net tangible assets of the Partnership or (b) 50% of the consolidated net income of the Partnership before interest, taxes, depreciation and amortization.

Minority Partner Redemption Date” has the meaning set forth in Section 11.01(n).

Minority Partner Redemption Notice” has the meaning set forth in Section 11.01(n).

Officer has the meaning set forth in Section 6.01(b).

Optionee means a Person to whom a stock option is granted under any Stock Option Plan.

Other Agreements has the meaning set forth in Section 10.04.

Partner means the General Partner or any Limited Partner.

Partner Minimum Gain means “partner nonrecourse debt minimum gain” as defined in Treasury Regulations Section 1.704-2(i)(3).

Partnership has the meaning set forth in the preamble to this Agreement.

Partnership Employee means an employee of, or other service provider to, the Partnership or any Subsidiary, in each case acting in such capacity.

Partnership Level Taxes” means any federal, state or local taxes, additions to tax, penalties and interest payable by the Partnership or any Subsidiary thereof as a result of any examination of the Partnership’s or any of its Subsidiaries’ affairs by any federal, state or local tax authorities, including resulting administrative and judicial proceedings under the Revised Partnership Audit Provisions.

Partnership Minimum Gain means “partnership minimum gain” determined pursuant to Treasury Regulations Section 1.704-2(d).

Partnership Representative has the meaning set forth in Section 9.03.

 

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Percentage Interest means, with respect to a Partner at a particular time, such Partner’s percentage interest in the Partnership determined by dividing such Partner’s Units by the total Units of all Partners at such time. The Percentage Interest of each Partner shall be calculated to the 4th decimal place, and the Percentage Interest with respect to the General Partner Interest shall at all times be zero.

Permitted Transfer has the meaning set forth in Section 10.02.

Person means an individual or any corporation, partnership, limited liability company, trust, unincorporated organization, association, joint venture or any other organization or entity, whether or not a legal entity.

Prior Limited Partnership Agreement has the meaning set forth in the recitals to this Agreement.

Pro rata,” proportional,” in proportion to,” and other similar terms, means, with respect to the holder of Units, pro rata based upon the number of such Units held by such holder as compared to the total number of Units outstanding.

Profits has the meaning set forth in Section 5.01(c).

Public Offering” means an underwritten offering and sale of Equity Securities to the public pursuant to a registration statement, including a “bought” deal or “overnight” public offering.

Reclassification Event means any of the following: (a) any reclassification or recapitalization of Common Stock (other than a change in par value, or from par value to no par value, or from no par value to par value, or as a result of a subdivision or combination or any transaction subject to Section 3.04), (b) any merger, consolidation or other combination involving the Corporation, or (c) any sale, conveyance, lease, or other disposal of all or substantially all the properties and assets of the Corporation to any other Person, in each of clauses (a), (b) or (c), as a result of which holders of Common Stock shall be entitled to receive cash, securities or other property for their shares of Common Stock.

Redeeming Partner has the meaning set forth in Section 11.01(a).

Redemption” means any redemption of Units into shares of Class A Common Stock or cash pursuant to this Agreement.

Redemption Date” means a Regular Redemption Date or a Special Redemption Date.

Redemption Notice has the meaning set forth in Section 11.01(b).

Redemption Notice Date means, except as otherwise specified by the General Partner to the extent necessary for the Corporation to comply with the Royal Registration Rights Agreement or the DPM Registration Rights Agreement, with respect to any Regular Redemption Date or Special Redemption Date, the date that is the (10) Business Days before such Redemption Date.

Redemption Right has the meaning set forth in Section 11.01(a).

 

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Registered Offering” means any secondary securities offering (which may include a “bought deal” or “overnight” offering), and any primary securities offering for which piggyback rights are offered, pursuant to the Royal Registration Rights Agreement or the DPM Registration Rights Agreement.

Regular Redemption Date” means a date within each fiscal quarter specified by the Corporation from time to time, which will generally be set so that the corresponding Redemption Notice Date falls within a window after the Corporation’s earnings announcement for the prior fiscal quarter or in connection with a Registered Offering.

Related Person has the meaning set forth in Section 7.01(c).

Relative means, with respect to any natural person: (a) such natural person’s spouse; (b) any lineal descendant, parent, grandparent, great grandparent or sibling or any lineal descendant of such sibling (in each case whether by blood or legal adoption); and (c) the spouse of a natural person described in clause (b) of this definition.

Revised Partnership Audit Provisions shall mean Section 1101 of Title XI (Revenue Provisions Related to Tax Compliance) of the Bipartisan Budget Act of 2015, H.R. 1314, Public Law Number 114-74.

Royal Closing means the “Closing” as defined in Section 1.1 of the Contribution Agreement.

Royal Contributor has the meaning set forth in the recitals to this Agreement.

Royal Registration Rights Agreement means that certain Registration Rights Agreement, dated as of August 23, 2018, by and among the Corporation and the Royal Contributors (other than Royal).

Royal Transactions means the “Transactions” as defined in Section 1.1 of the Contribution Agreement.

SEC means the U.S. Securities and Exchange Commission, including any governmental body or agency succeeding to the functions thereof.

SEC Guidance means (a) any publicly available written or oral interpretations, questions and answers, guidance and forms of the SEC, (b) any oral or written comments, requirements or requests of the SEC or its staff, (c) the Securities Act and the Exchange Act and (d) any other rules, bulletins, releases, manuals and regulations of the SEC.

Securities Act means the Securities Act of 1933, as amended, and applicable rules and regulations thereunder, and any successor to such statute, rules or regulations. Any reference herein to a specific section, rule or regulation of the Securities Act shall be deemed to include any corresponding provisions of future Law.

 

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Simulated Basis means, with respect to each Depletable Property, the Book Value of such property. For purposes of such computation, the Simulated Basis of each Depletable Property (including any additions to such Simulated Basis resulting from expenditures required to be capitalized in such Simulated Basis) shall be allocated to each Partner in accordance with such Partner’s relative Percentage Interest as of the time such Depletable Property (or such addition to such Simulated Basis resulting from expenditures required to be capitalized in such Simulated Basis) is acquired (or expended) by the Partnership, and shall be reallocated among the Partners in accordance with the Partners’ Percentage Interests as determined immediately following the occurrence of an event giving rise to an adjustment to the Book Value of the Partnership’s Depletable Properties pursuant to the definition of Book Value. Upon a transfer by a Partner of any Units, a portion of the Simulated Basis allocated to such Partner shall be reallocated to the transferee in accordance with the relative Percentage Interest transferred.

Simulated Depletion means, with respect to each Depletable Property, a depletion allowance computed in accordance with U.S. federal income tax principles and in a manner specified in Treasury Regulations Section 1.704-1(b)(2)(iv)(k)(2), using the depletion method selected by the General Partner. For purposes of computing Simulated Depletion with respect to any Depletable Property, the Simulated Basis of such property shall be deemed to be the Book Value of such property, and in no event shall such allowance, in the aggregate, exceed the Simulated Basis of such Depletable Property. If the Book Value of a Depletable Property is adjusted pursuant to the definition of Book Value during a Taxable Year or other Fiscal Period, following such adjustment Simulated Depletion shall thereafter be calculated under the foregoing provisions based upon such adjusted Book Value.

Simulated Gain means the excess, if any, of the amount realized from the sale or other disposition of a Depletable Property over the Book Value of such Depletable Property and determined pursuant to Treasury Regulations Section 1.704-1(b)(2)(iv)(k)(2).

Simulated Loss means the excess, if any, of the Book Value of a Depletable Property over the amount realized from the sale or other disposition of such Depletable Property and determined pursuant to Treasury Regulations Section 1.704-1(b)(2)(iv)(k)(2).

Source Parties” means Source Energy Leasehold, LP, Permian Mineral Acquisitions, LP and their respective Affiliates.

Special Redemption Date” means a date specified by the Corporation in addition to or in lieu of the Regular Redemption Date during the same fiscal quarter. The Corporation must specify a Special Redemption Date effective with any Registered Offering.

Sponsor Person has the meaning set forth in Section 7.04(d).

Stock Exchange means the NASDAQ Capital Market.

Stock Option Plan means any stock option plan now or hereafter adopted by the Partnership or by the Corporation.

Subsidiary means, with respect to any Person, any corporation, limited liability company, partnership, association or business entity of which (a) if a corporation, a majority of the total voting power of shares of stock entitled (without regard to the occurrence of any contingency) to vote in the election of directors, managers or trustees thereof is at the time owned

 

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or controlled, directly or indirectly, by that Person or one or more of the other Subsidiaries of that Person or a combination thereof, or (b) if a limited liability company, partnership, association or other business entity (other than a corporation), a majority of the voting interests thereof are at the time owned or controlled, directly or indirectly, by any Person or one or more Subsidiaries of that Person or a combination thereof. For purposes hereof, references to a “Subsidiary” of the Partnership shall be given effect only at such times that the Partnership has one or more Subsidiaries, and, unless otherwise indicated, the term “Subsidiary” refers to a Subsidiary of the Partnership.

Substituted Limited Partner means a Person that is admitted as a Limited Partner to the Partnership pursuant to Section 12.01 with all of the rights of a Limited Partner and who is shown as a Limited Partner on the books and records of the Partnership.

Taxable Year means the Partnership’s accounting period for U.S. federal income tax purposes determined pursuant to Section 9.02.

Trading Day means a day on which the Stock Exchange or such other principal United States securities exchange on which the Class A Common Stock is listed or admitted to trading is open for the transaction of business (unless such trading shall have been suspended for the entire day).

Transfer (and, with a correlative meaning, “Transferring”) means any sale, transfer, assignment, pledge, encumbrance or other disposition of (whether directly or indirectly, whether with or without consideration and whether voluntarily or involuntarily or by operation of Law) (a) any interest (legal or beneficial) in any Equity Securities of the Partnership or (b) any equity or other interest (legal or beneficial) in any Partner if substantially all of the assets of such Partner consist solely of Units.

Treasury Regulations means the regulations promulgated under the Code and any corresponding provisions of succeeding regulations.

Unit means a Limited Partner Interest of a Limited Partner or a permitted Assignee in the Partnership and shall include Common Units, but shall not include the General Partner Interest.

Unvested Corporate Shares means shares of Class A Common Stock issued pursuant to an Equity Plan that are not vested pursuant to the terms thereof or any award or similar agreement relating thereto.

Value means (a) for any Stock Option Plan, the Market Price for the Trading Day immediately preceding the date of exercise of a stock option under such Stock Option Plan and (b) for any Equity Plan other than a Stock Option Plan, the Market Price for the Trading Day immediately preceding the Vesting Date.

Vesting Date has the meaning set forth in Section 3.10(c).

Voting Securities means any Equity Securities of the Corporation that are entitled to vote generally in matters submitted for a vote of the Corporation’s stockholders or generally in the election of the Corporate Board.

 

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VWAP” per share of Class A Common Stock on any Trading Day shall mean the per share of Class A Common Stock volume-weighted average price as displayed under the heading “Bloomberg VWAP” on Bloomberg page for the Class A Common Stock (or its equivalent successor if such page is not available) in respect of the period from the scheduled open of trading until the scheduled close of trading of the primary trading session on such Trading Day (or if such volume-weighted average price is unavailable, the closing price of one share of Class A Common Stock on such Trading Day as reported on the website of the NYSE or such other national securities exchange upon which the shares of Class A Common Stock are listed). If the VWAP cannot be calculated for shares of Class A Common Stock on a particular date on any of the foregoing bases, the VWAP of the shares of Class A Common Stock on such date shall be the fair market value as determined in good faith by the General Partner in a commercially reasonable manner.

Warrants has the meaning set forth in Section 3.03(a).

ARTICLE II

ORGANIZATIONAL MATTERS

Section 2.01 Formation of Partnership. The Partnership was formed on May 31, 2018 pursuant to the provisions of the Delaware Act.

Section 2.02 Second Amended and Restated Limited Partnership Agreement. The Partners hereby execute this Agreement for the purpose of continuing the affairs of the Partnership and the conduct of its business in accordance with the provisions of the Delaware Act. The Partners hereby agree that during the term of the Partnership set forth in Section 2.06, the rights and obligations of the Partners with respect to the Partnership will be determined in accordance with the terms and conditions of this Agreement and the Delaware Act. On any matter upon which this Agreement is silent, the Delaware Act shall control. No provision of this Agreement shall be in violation of the Delaware Act and, to the extent any provision of this Agreement is in violation of the Delaware Act, such provision shall be void and of no effect to the extent of such violation without affecting the validity of the other provisions of this Agreement; provided, however, that where the Delaware Act provides that a provision of the Delaware Act shall apply “unless otherwise provided in a limited partnership agreement” or words of similar effect, the relevant provisions of this Agreement shall in each instance control; provided further, that notwithstanding the foregoing, Section 15-120 of the Delaware Act shall not apply or be incorporated into this Agreement.

Section 2.03 Name. The name of the Partnership shall be “Sitio Royalties Operating Partnership, LP.” The General Partner in its sole discretion may change the name of the Partnership at any time and from time to time. Notification of any such change shall be given to all of the Partners and, to the extent practicable, to all of the holders of any Equity Securities then outstanding. The Partnership’s business may be conducted under its name and/or any other name or names deemed advisable by the General Partner.

Section 2.04 Purpose. The primary business and purpose of the Partnership shall be to engage in such activities as are permitted under the Delaware Act and determined from time to time by the General Partner in accordance with the terms and conditions of this Agreement.

 

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Section 2.05 Principal Office; Registered Office. The principal office of the Partnership shall be at 1144 15th Street, Suite 2650, Denver, Colorado 80202, or such other place as the General Partner may from time to time designate. The address of the registered office of the Partnership in the State of Delaware shall be 1000 North King Street, in the City of Wilmington, Delaware 19801, and the registered agent for service of process on the Partnership in the State of Delaware at such registered office shall be the Corporation Guarantee and Trust Company. The General Partner may from time to time change the Partnership’s registered agent and registered office in the State of Delaware.

Section 2.06 Term. The term of the Partnership commenced upon the filing of the Certificate in accordance with the Delaware Act and shall continue in existence until termination and dissolution of the Partnership in accordance with the provisions of Article XIV.

Section 2.07 No Joint Venture. The Partners intend that the Partnership not be a joint venture, and that no Partner be a joint venturer of any other Partner by virtue of this Agreement, and neither this Agreement nor any other document entered into by the Partnership or any Partner relating to the subject matter hereof shall be construed to suggest otherwise.

ARTICLE III

PARTNERS; UNITS; CAPITALIZATION

Section 3.01 Partners.

(a) The Limited Partners previously admitted as Limited Partners shall each remain as a Limited Partner of the Partnership and the General Partner previously admitted as the sole general partner of the Partnership shall remain the sole general partner of the Partnership, in each case, upon the Effective Time. At the Effective Time and concurrently with the DPM Closing, each DPM Holder shall be admitted to the Partnership as a Limited Partner.

(b) The Partnership shall maintain a schedule setting forth: (i) the name and address of each Limited Partner; (ii) the aggregate number of outstanding Units and the number and class of Units held by each Limited Partner; (iii) the aggregate amount of cash Capital Contributions that have been made by the Limited Partners with respect to their Units; and (iv) the Fair Market Value of any property other than cash contributed by the Limited Partners with respect to their Units (including, if applicable, a description and the amount of any liability assumed by the Partnership or to which contributed property is subject) (such schedule, the “Schedule of Limited Partners”). The applicable Schedule of Limited Partners in effect as of the Effective Time (after giving effect to the transactions contemplated by the DPM Merger Agreement) is set forth as Schedule 1 to this Agreement. The Schedule of Limited Partners shall be the definitive record of ownership of each Unit of the Partnership and all relevant information with respect to each Limited Partner. The Partnership shall be entitled to recognize the exclusive right of a Person registered on its records as the owner of Units for all purposes and shall not be bound to recognize any equitable or other claim to or interest in Units on the part of any other Person, whether or not it shall have express or other notice thereof, except as otherwise provided by the Delaware Act.

(c) No Limited Partner shall be required or, except as approved by the General Partner pursuant to Section 6.01 and in accordance with the other provisions of this Agreement, permitted to loan any money or property to the Partnership or borrow any money or property from the Partnership.

 

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Section 3.02 Units. Interests in the Partnership shall be represented by Units, or such other securities of the Partnership, in each case as the General Partner may establish in its discretion in accordance with the terms and subject to the restrictions hereof. The Units are comprised of a single class of Common Units. Without limiting the foregoing, to the extent required pursuant to Section 3.04(a), the General Partner may create one or more classes or series of Common Units or preferred Units solely to the extent they are in the aggregate substantially equivalent to a class of common stock of the Corporation or class or series of preferred stock of the Corporation.

Section 3.03 Contribution Agreement and DPM Merger Agreement.

(a) Corporation Contribution. Pursuant to the Contribution Agreement, at the Royal Closing, the Corporation contributed, assigned, transferred, conveyed and delivered to the Partnership cash in the aggregate amount of $382,217,254.88 in exchange for (i) 45,855,000 Common Units and (ii) warrants (the “Warrants”) exercisable for a number of Common Units equal to the number of shares of Class A Common Stock underlying the warrants of the Corporation outstanding immediately prior to such issuance of Warrants . Each Warrant shall be treated as a “noncompensatory option” within the meaning of Treasury Regulations Sections 1.721-2(f) and 1.761-3(b)(2) and shall not be treated as a partnership interest pursuant to Treasury Regulations Section 1.761-3(a) unless otherwise required pursuant to a “determination” within the meaning of Section 1313 of the Code (or analogous provision of state, local or non-U.S. Law).

(b) Royal Contribution. Pursuant to the Contribution Agreement, at the Royal Closing, each Royal Contributor contributed, assigned, transferred, conveyed and delivered to the Partnership, free and clear of all Liens (other than transfer restrictions under applicable securities Laws) the Contributed Interests owned by each such Royal Contributor and, was issued Common Units in an amount contemplated by the Contribution Agreement.

(c) DPM Merger Agreement. Pursuant to the DPM Merger Agreement, at the DPM Closing and prior to giving effect to Section 3.04, each DPM Holder was issued the number of Common Units set forth next to each such DPM Holder’s name on Schedule 1, which Common Units are hereby issued and outstanding as of the Effective Time.

Section 3.04 Authorization and Issuance of Additional Units.

(a) The Partnership shall, to the fullest extent permitted by Law, undertake all actions, including, without limitation, a reclassification, dividend, division or recapitalization, with respect to the Equity Securities of the Partnership necessary to maintain at all times a one-to-one ratio between the number of Common Units owned by the Corporation Holdings Group and the number of outstanding shares of Class A Common Stock. In addition to and without limiting the foregoing, if at any time the Corporation issues a share of its Class A Common Stock or any other Equity Security of the Corporation (other than Class C Common Stock), (i) the Partnership shall issue to the applicable member(s) of the Corporation Holdings Group one Common Unit (if the Corporation issues a share of Class A Common Stock), or such other Equity Security of the

 

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Partnership (if the Corporation issues Equity Securities other than Class A Common Stock) corresponding to such Equity Securities issued by the Corporation, and with substantially the same rights to dividends and distributions (including distributions upon liquidation but taking into account differences as a result of any tax or other liabilities borne by the Corporation) and other economic rights as those of such Equity Securities of the Corporation and (ii) the net proceeds received by the applicable member(s) of the Corporation Holdings Group with respect to the issuance of the corresponding share of Class A Common Stock or other Equity Security, if any, shall be concurrently contributed by such member(s) to the Partnership as a Capital Contribution; provided, that if the Corporation issues any shares of Class A Common Stock in order to directly purchase from another Partner (other than a member of the Corporation Holdings Group) a number of Common Units pursuant to Section 11.01(m) (and a corresponding number of shares of Class C Common Stock), then the Partnership shall not issue any new Common Units in connection therewith and the Corporation Holdings Group shall not be required to Transfer such net proceeds to the Partnership (it being understood that such net proceeds shall instead be transferred to such other Partner as consideration for such purchase). For the avoidance of doubt, if the Corporation issues any shares of Class A Common Stock or other Equity Security for cash to be used to fund the acquisition by any member of the Corporation Holdings Group of any Person or the assets of any Person, then the Corporation shall not be required to transfer such cash proceeds to the Partnership but instead such member of the Corporation Holdings Group shall be required to contribute such Person or the assets and liabilities of such Person to the Partnership or any of its Subsidiaries. Notwithstanding the foregoing, this Section 3.04(a) shall not apply to (A) (1) the issuance and distribution to holders of shares of Class A Common Stock of rights to purchase Equity Securities of the Corporation under a “poison pill” or similar shareholders rights plan (it being understood that upon exchange of Units for Class A Common Stock, such Class A Common Stock will be issued together with a corresponding right) or (2) the issuance under the Corporation’s Equity Plans or Stock Option Plans of any warrants, options, other rights to acquire Equity Securities of the Corporation or rights or property that may be converted into or settled in Equity Securities of the Corporation, but shall in each of the foregoing cases apply to the issuance of Equity Securities of the Corporation in connection with the exercise or settlement of such rights, warrants, options or other rights or property, (B) the issuance of Equity Securities pursuant to any Equity Plan (other than a Stock Option Plan) that are restricted, subject to forfeiture or otherwise unvested upon issuance, but shall apply on the applicable Vesting Date with respect to such Equity Securities or (C) preferred stock or other debt or equity securities (including without limitation warrants, options and rights) issued by the Corporation that are convertible or exercisable or exchangeable for Class A Common Stock (except to the extent such securities have been converted, exercised or exchanged for Class A Common Stock and the net proceeds from such other securities, including without limitation any exercise or purchase price payable upon conversion, exercise or exchange thereof, has been contributed by the Corporation Holdings Group to the equity capital of the Partnership). Except pursuant to this Section 3.04(a) and Article XI, (x) the Partnership may not issue any additional Common Units to one or more members of the Corporation Holdings Group unless substantially simultaneously therewith such member(s) of the Corporation Holdings Group issues or sells an equal number of shares of the Corporation’s Class A Common Stock to another Person, and (y) the Partnership may not issue any other Equity Securities of the Partnership to one or more members of the Corporation Holdings Group unless substantially simultaneously therewith such members of the Corporation Holdings Group issues or sells, to another Person, an equal number of shares of a new class or series of Equity Securities

 

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of the Corporation or such member(s) of the Corporation Holdings Group with substantially the same rights to dividends and distributions (including distributions upon liquidation but taking into account differences as a result of any tax or other liabilities borne by the Corporation) and other economic rights as those of such Equity Securities of the Partnership.

(b) The Partnership shall only be permitted to issue additional Units or other Equity Securities in the Partnership to the Persons and on the terms and conditions provided for in Section 3.02, this Section 3.04 and Section 3.11.

(c) The Partnership shall not in any manner effect any subdivision (by equity split, equity distribution, reclassification, recapitalization or otherwise) or combination (by reverse equity split, reclassification, recapitalization or otherwise) of the outstanding Common Units unless accompanied by an identical subdivision or combination, as applicable, of the outstanding Common Stock, with corresponding changes made with respect to any other exchangeable or convertible securities. Unless in connection with any action taken pursuant to Section 3.04(d), the Corporation shall not in any manner effect any subdivision (by stock split, stock dividend, reclassification, recapitalization or otherwise) or combination (by reverse stock split, reclassification, recapitalization or otherwise) of the outstanding Common Stock unless accompanied by an identical subdivision or combination, as applicable, of the outstanding Common Units, with corresponding changes made with respect to any other exchangeable or convertible securities. The Partnership shall not in any manner effect any subdivision (by equity split, equity distribution, reclassification, recapitalization or otherwise) or combination (by reverse equity split, reclassification, recapitalization or otherwise) of any outstanding Equity Securities of the Partnership (other than the Common Units) unless accompanied by an identical subdivision or combination, as applicable, of the corresponding Equity Securities of the Corporation, with corresponding changes made with respect to any other exchangeable or convertible securities. The Corporation shall not in any manner effect any subdivision (by stock split, stock dividend, reclassification, recapitalization or otherwise) or combination (by reverse stock split, reclassification, recapitalization or otherwise) of any outstanding Equity Securities of the Corporation (other than the Common Stock) unless accompanied by an identical subdivision or combination, as applicable, of the corresponding Equity Securities of the Partnership, with corresponding changes made with respect to any other exchangeable or convertible securities.

(d) Notwithstanding any other provision of this Agreement, if the Corporation receives tax distributions required to be made pursuant to Section 4.01(b) in an amount in excess of the amount that will enable the Corporation Holdings Group to meet its U.S. federal, state and local and non-U.S. tax liabilities, or holds any other excess cash amount, the Corporation may, in its sole discretion, use such excess cash amount in such manner, and make such adjustments to or take such other actions with respect to the capitalization of the Corporation and the Partnership, as the Corporation in good faith determines to be fair and reasonable to the holders of Common Stock and to the Partners and to preserve the intended economic effect of this Section 3.04, Section 3.05, Article XI and the other provisions hereof.

(e) If at any time any member of the Corporation Holdings Group issues debt securities, such member of the Corporation Holdings Group shall transfer to the Partnership (in a manner to be determined by the General Partner in its reasonable discretion) the proceeds received by such member of the Corporation Holdings Group in exchange for such debt securities in a manner that directly or indirectly burdens the Partnership with the repayment of the debt securities.

 

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(f) Notwithstanding any other provision of this Agreement (including this Section 3.04 and Section 3.05), the Partnership may redeem Units from the Corporation Holdings Group for cash to fund any acquisition by the Corporation Holdings Group of another Person, provided that promptly after such redemption and acquisition the Corporation Holdings Group contributes or causes to be contributed, directly or indirectly, such Person or the assets and liabilities of such Person to the Company or any of its Subsidiaries in exchange for a number of Units equal to the number of Units so redeemed.

Section 3.05 Repurchases or Redemptions. No member of the Corporation Holdings Group may redeem, repurchase or otherwise acquire (other than from another member of the Corporation Holdings Group) (a) any shares of Class A Common Stock unless substantially simultaneously therewith the Partnership redeems, repurchases or otherwise acquires from the Corporation Holdings Group an equal number of Common Units for the same price per security or (b) any other Equity Securities of the Corporation (other than Class C Common Stock) unless substantially simultaneously therewith the Partnership redeems, repurchases or otherwise acquires from the Corporation Holdings Group an equal number of Equity Securities of the Partnership of a corresponding class or series with substantially the same rights to dividends and distributions (including distributions upon liquidation but taking into account differences as a result of any tax or other liabilities borne by the Corporation) and other economic rights as those of such Equity Securities of the Corporation for the same price per security. The Partnership may not redeem, repurchase or otherwise acquire (i) except pursuant to Article XI, any Common Units from the Corporation Holdings Group unless substantially simultaneously therewith the Corporation Holdings Group redeems, repurchases or otherwise acquires an equal number of shares of Class A Common Stock for the same price per security from holders thereof, or (ii) any other Equity Securities of the Partnership from the Corporation Holdings Group unless substantially simultaneously the Corporation Holdings Group redeems, repurchases or otherwise acquires for the same price per security an equal number of Equity Securities of the Corporation of a corresponding class or series with substantially the same rights to dividends and distributions (including distribution upon liquidation but taking into account differences as a result of any tax or other liabilities borne by the Corporation) and other economic rights as those of such Equity Securities of the Partnership. Notwithstanding the foregoing, to the extent that any consideration payable by the Corporation Holdings Group in connection with the redemption or repurchase of any shares of Class A Common Stock or other Equity Securities of the Corporation Holdings Group consists (in whole or in part) of shares of Class A Common Stock or such other Equity Securities (including in connection with the cashless exercise of an option or warrant), then the redemption or repurchase of the corresponding Common Units or other Equity Securities of the Partnership shall be effectuated in an equivalent manner.

 

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Section 3.06 Certificates Representing Units; Lost, Stolen or Destroyed Certificates; Registration and Transfer of Units.

(a) Units shall not be certificated unless otherwise determined by the General Partner. If the General Partner determines that one or more Units shall be certificated, each such certificate shall be signed by or in the name of the Partnership, by the Chief Executive Officer and any other officer designated by the General Partner, representing the number of Units held by such holder. Such certificate shall be in such form (and shall contain such legends) as the General Partner may determine. Any or all of such signatures on any certificate representing one or more Units may be a facsimile, engraved or printed, to the extent permitted by applicable Law. The General Partner agrees that it shall not elect to treat any Unit as a “security” within the meaning of Article 8 of the Uniform Commercial Code unless thereafter all Units then outstanding are represented by one or more certificates.

(b) If Units are certificated, the General Partner may direct that a new certificate representing one or more Units be issued in place of any certificate theretofore issued by the Partnership alleged to have been lost, stolen or destroyed, upon delivery to the General Partner of an affidavit of the owner or owners of such certificate, setting forth such allegation. The General Partner may require the owner of such lost, stolen or destroyed certificate, or such owner’s legal representative, to give the Partnership a bond sufficient to indemnify it against any claim that may be made against it on account of the alleged loss, theft or destruction of any such certificate or the issuance of any such new certificate.

(c) Upon surrender to the Partnership or the transfer agent of the Partnership, if any, of a certificate for one or more Units, duly endorsed or accompanied by appropriate evidence of succession, assignment or authority to transfer, in compliance with the provisions hereof, the Partnership shall issue a new certificate representing one or more Units to the Person entitled thereto, cancel the old certificate and record the transaction upon its books. Subject to the provisions of this Agreement, the General Partner may prescribe such additional rules and regulations as it may deem appropriate relating to the issue, Transfer and registration of Units.

Section 3.07 Negative Capital Accounts. No Partner shall be required to pay to any other Partner or the Partnership any deficit or negative balance which may exist from time to time in such Partner’s Capital Account (including upon and after dissolution of the Partnership).

Section 3.08 No Withdrawal. No Person shall be entitled to withdraw any part of such Person’s Capital Contribution or Capital Account or to receive any Distribution from the Partnership, except as expressly provided in this Agreement.

Section 3.09 Loans From Partners. Loans by Partners to the Partnership shall not be considered Capital Contributions. Subject to the provisions of Section 3.01(c), the amount of any such advances shall be a debt of the Partnership to such Partner and shall be payable or collectible in accordance with the terms and conditions upon which such advances are made.

Section 3.10 Tax Treatment of Corporate Stock Option Plans and Equity Plans.

(a) Options Granted to Persons other than Partnership Employees. If at any time or from time to time, in connection with any Stock Option Plan, a stock option granted over shares of Class A Common Stock to a Person other than a Partnership Employee is duly exercised, notwithstanding the amount of the Capital Contribution actually made pursuant to Section 3.04(a), solely for U.S. federal (and applicable state and local) income tax purposes, the Corporation shall be deemed to have contributed to the Partnership as a Capital Contribution, in lieu of the Capital Contribution actually made and in consideration of additional Common Units, an amount equal to the Value of a share of Class A Common Stock as of the date of such exercise multiplied by the number of shares of Class A Common Stock then being issued by the Corporation in connection with the exercise of such stock option.

 

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(b) Options Granted to Partnership Employees. If at any time or from time to time, in connection with any Stock Option Plan, a stock option granted over shares of Class A Common Stock to a Partnership Employee is duly exercised, solely for U.S. federal (and applicable state and local) income tax pm-poses, the following transactions shall be deemed to have occurred:

(i) The Corporation shall have sold to the Optionee, and the Optionee shall have purchased from the Corporation, the number of shares of Class A Common Stock equal to the number of shares of Class A Common Stock as to which such stock option is exercised multiplied by the following: (x) the exercise price payable by the Optionee in connection with the exercise of such stock option divided by (y) the Value of a share of Class A Common Stock at the time of such exercise.

(ii) The Corporation shall have sold to the Partnership (or, if the Optionee is an employee of, or other service provider to, a Subsidiary, the Corporation shall sell to such Subsidiary), and the Partnership (or such Subsidiary, as applicable) shall have purchased from the Corporation, a number of shares of Class A Common Stock equal to the excess of (x) the number of shares of Class A Common Stock as to which such stock option is being exercised over (y) the number of shares of Class A Common Stock sold pursuant to Section 3.10(b)(i) hereof. The purchase price per share of Class A Common Stock for such sale of shares of Class A Common Stock to the Partnership (or such Subsidiary) shall be the Value of a share of Class A Common Stock as of the date of exercise of such stock option.

(iii) The Partnership shall have transferred to the Optionee (or, if the Optionee is an employee of, or other service provider to, a Subsidiary, the Subsidiary shall have transferred to the Optionee) at no additional cost to such Partnership Employee and as additional compensation to such Partnership Employee, the number of shares of Class A Common Stock described in Section 3.10(b)(ii).

(iv) The Corporation shall have contributed any amounts deemed received by the Corporation pursuant to Section 3.10(b)(i) and any amount deemed to be received by the Partnership pursuant to Section 3.10(b)(ii) in connection with the exercise of such stock option.

The transactions described in this Section 3.10(b) are intended to comply with the provisions of Treasury Regulations Section 1.1032-3 and shall be interpreted consistently therewith.

(c) Restricted Stock Granted to Partnership Employees. If at any time or from time to time, in connection with any Equity Plan (other than a Stock Option Plan), any shares of Class A Common Stock are issued to a Partnership Employee (including any shares of Class A Common Stock that are subject to forfeiture in the event such Partnership Employee terminates his or her employment with the Partnership or any Subsidiary) in consideration for services performed for the Partnership or any Subsidiary, on the date (such date, the “Vesting Date”) that the Value of such shares is includible in taxable income of such Partnership Employee, the

 

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following events will be deemed to have occurred solely for U.S. federal (and applicable state and local) income tax purposes: (i) the Corporation shall have sold such shares of Class A Common Stock to the Partnership (or, if such Partnership Employee is an employee of, or other service provider to, a Subsidiary, to such Subsidiary) for a purchase price equal to the Value of such shares of Class A Common Stock, (ii) the Partnership (or such Subsidiary) shall have delivered such shares of Class A Common Stock to such Partnership Employee, (iii) the Corporation shall have contributed the purchase price for such shares of Class A Common Stock to the Partnership as a Capital Contribution, and (iv) in the case where such Partnership Employee is an employee of a Subsidiary, the Partnership shall have contributed such amount to the capital of the Subsidiary.

(d) Future Stock Incentive Plans. Nothing in this Agreement shall be construed or applied to preclude or restrain the Corporation from adopting, modifying or terminating stock incentive plans for the benefit of employees, directors or other business associates of the Corporation, the Partnership or any of their respective Affiliates. The Partners acknowledge and agree that, in the event that any such plan is adopted, modified or terminated by the Corporation, amendments to this Section 3.10 may become necessary or advisable and that any approval or consent to any such amendments requested by the Corporation shall be deemed granted by the General Partner without the requirement of any further consent or acknowledgement of any other Partner.

(e) Anti-dilution Adjustments. For all purposes of this Section 3.10, the number of shares of Class A Common Stock and the corresponding number of Common Units shall be determined after giving effect to all anti-dilution or similar adjustments that are applicable, as of the date of exercise or vesting, to the option, warrant, restricted stock or other equity interest that is being exercised or becomes vested under the applicable Stock Option Plan or other Equity Plan and applicable award or grant documentation.

Section 3.11 Dividend Reinvestment Plan, Cash Option Purchase Plan, Stock Incentive Plan or Other Plan. Except as may otherwise be provided in this Article III, all amounts received or deemed received by the Corporation in respect of any dividend reinvestment plan, cash option purchase plan, stock incentive or other stock or subscription plan or agreement, either (a) shall be utilized by the Corporation to effect open market purchases of shares of Class A Common Stock, or (b) if the Corporation elects instead to issue new shares of Class A Common Stock with respect to such amounts, shall be contributed by the Corporation to the Partnership in exchange for additional Units. Upon such contribution, the Partnership will issue to the Corporation a number of Units equal to the number of new shares of Class A Common Stock so issued.

Section 3.12 Deemed Capital ContributionsSection 3.13 . Consistent with the principles of Treasury Regulation Section 1.83-6(d), if any Partner (or its successor) transfers property (including cash) to any Partnership Employee or other service provider of the Partnership or any Subsidiary and such Partner is not entitled to be reimbursed by (or otherwise elects not to seek reimbursement from) the Partnership for the value of such property, then for tax purposes, (a) such property shall be treated as having been contributed to the Partnership by such Partner and (b) immediately thereafter the Partnership shall be treated as having transferred such property to the Partnership Employee or other service provider.

 

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ARTICLE IV

DISTRIBUTIONS

Section 4.01 Distributions.

(a) Distributable Cash; Other Distributions. To the extent permitted by applicable Law and hereunder, Distributions to Limited Partners may be declared by the General Partner out of Distributable Cash or other funds or property legally available therefor in such amounts and on such terms (including the payment dates of such Distributions) as the General Partner shall determine using such record date as the General Partner may designate; such Distributions shall be made to the Limited Partners as of the close of business on such record date on a pro rata basis in accordance with each Limited Partner’s Percentage Interest as of the close of business on such record date; provided, however, that the General Partner shall have the obligation to make Distributions as set forth in Section 4.01(b), Section 6.05 and Section 14.02; and provided further that, notwithstanding any other provision herein to the contrary, no Distributions shall be made to any Limited Partner to the extent such Distribution would violate Section 15-309 of the Delaware Act. Promptly following the designation of a record date and the declaration of a Distribution pursuant to this Section 4.01(a), the General Partner shall give notice to each Limited Partner of the record date, the amount and the terms of the Distribution and the payment date thereof.

(b) Tax Distributions. The Partnership shall, subject to any restrictions contained in any agreement to which the Partnership is bound, make distributions out of legally available funds to all Partners on a pro rata basis in accordance with Section 4.01(a) at such times and in such amounts as the General Partner reasonably determines is necessary to cause a distribution to the Corporation sufficient to enable the Corporation to timely satisfy any Corporate Tax Liabilities.

Section 4.02 Restricted Distributions. Notwithstanding any provision to the contrary contained in this Agreement, the Partnership shall not make any Distribution to any Partner on account of any Limited Partner Interest if such Distribution would violate any applicable Law or the terms of the Credit Agreement or other debt financing of the Partnership or its Subsidiaries.

ARTICLE V

CAPITAL ACCOUNTS; ALLOCATIONS; TAX MATTERS

Section 5.01 Capital Accounts.

(a) The Partnership shall maintain a separate Capital Account for each Partner according to the rules of Treasury Regulations Section 1.704-1(b)(2)(iv). For this purpose, the Partnership may (in the discretion of the General Partner), upon the occurrence of the events specified in Treasury Regulations Section 1.704-1(b)(2)(iv)(f) and Treasury Regulations Section 1.704-1(b)(2)(iv)(g), increase or decrease the Capital Accounts in accordance with the rules of such Treasury Regulations to reflect a revaluation of Partnership property.

 

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(b) The Capital Account of each Partner shall be increased by (i) the amount of any cash and the initial Book Value of any property contributed to the Partnership by such Partner (net of any liability secured by such contributed property that the Partnership is considered to assume or take subject to); and (ii) the amounts of Profit allocated to such Partner pursuant to Section 5.02 and any items in the nature of income or gain that are specially allocated to such Partner pursuant to Section 5.03. The Capital Account of each Partner shall be reduced by (A) the amount of any cash and the Book Value of any property distributed to such Partner by the Partnership (net of liabilities secured by such distributed property that such Partner is considered to assume or take subject to); and (B) the amounts of Loss allocated to such Partner pursuant to Section 5.02 and any items in the nature of loss or deduction that are specially allocated to such Partner pursuant to Section 5.03. The Capital Account of each Partner shall otherwise be adjusted in accordance with the rules set forth in Treasury Regulations Section 1.704-1(b)(2)(iv). If any property other than cash is distributed to a Partner, the Capital Account of such Partner shall be adjusted as if the property had instead been sold by the Partnership for a price equal to its fair market value, and the proceeds thereafter distributed to such Partner.

(c) The amount of “Profit” or “Loss” with respect to a Taxable Year or Fiscal Period means an amount equal to the Partnership’s taxable income or loss for such Taxable Year or Fiscal Period, determined in accordance with Section 703(a) (including separately stated items), with the following adjustments:

(i) the computation of all items of income, gain, loss and deduction shall include those items described in Code Section 705(a)(1)(B) or Code Section 705(a)(2)(B) and Treasury Regulations Section 1.704-1(b)(2)(iv)(i), without regard to the fact that such items are not includable in gross income or are not deductible for U.S. federal income tax purposes;

(ii) if the Book Value of any Partnership property is adjusted pursuant to Treasury Regulations Section 1.704-1(b)(2) (iv)(e) or (f), the amount of such adjustment shall be taken into account as gain or loss from the disposition of such property;

(iii) items of income, gain, loss or deduction attributable to the disposition of Partnership property having a Book Value that differs from its adjusted basis for tax purposes shall be computed by reference to the Book Value of such property;

(iv) in lieu of depreciation, amortization and other cost recovery deductions (excluding depletion with respect to a Depletable Property), there shall be taken into account Depreciation for such Taxable Year or other Fiscal Period;

(v) to the extent an adjustment to the adjusted tax basis of any Partnership asset pursuant to Code Sections 732(d), 734(b) or 743(b) is required, pursuant to Treasury Regulations Section 1.704-1(b)(2)(iv)(m), to be taken into account in determining Capital Accounts, the amount of such adjustment to the Capital Accounts shall be treated as an item of gain (if the adjustment increases the basis of the asset) or loss (if the adjustment decreases such basis);

(vi) Simulated Gains with respect to Depletable Properties shall be taken into account in lieu of actual gains on such Depletable Properties; and

(vii) items specifically allocated under Section 5.03 shall be excluded.

 

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Section 5.02 Book Allocations. After giving effect to the allocations under Section 5.03, Profits and Losses (and to the extent determined necessary and appropriate by the General Partner to achieve the resulting Capital Account balances described below, any allocable items of gross income, gain, loss and expense includable in the computation of Profits and Losses) for any Taxable Year or other Fiscal Period shall be allocated among the Capital Accounts of the Partners pro rata in accordance with their Percentage Interests.

Section 5.03 Regulatory and Special Allocations.

(a) Partner nonrecourse deductions (as defined in Treasury Regulations Section 1.704-2(i)(2)) attributable to partner nonrecourse debt (as defined in Treasury Regulations Section 1.704-2(b)(4)) shall be allocated in the manner required by Treasury Regulations Section 1.704-2(i). If there is a net decrease during a Taxable Year or other Fiscal Period in Partner Minimum Gain, items of income and gain for such Taxable Year or other Fiscal Period (and, if necessary, for subsequent Taxable Years or periods) shall be allocated to the Partners in the amounts and of such character as determined according to Treasury Regulations Section 1.704-2(i)(4). This Section 5.03(a) is intended to comply with the minimum gain chargeback requirements set forth in Treasury Regulations Section 1.704-2(i)(4) and shall be interpreted consistently therewith.

(b) Nonrecourse deductions (as determined according to Treasury Regulations Section 1.704-2(b)(1)) for any Taxable Year or Fiscal Period shall be allocated pro rata among the Partners in accordance with their Percentage Interests. Except as otherwise provided in Treasury Regulations Section 1.704-2(f), if there is a net decrease in the Partnership Minimum Gain during any Taxable Year or other Fiscal Period, each Partner shall be allocated items of income and gain for such Taxable Year or other Fiscal Period (and, if necessary, for subsequent Taxable Years or periods) in the amounts and of such character as determined according to Treasury Regulations Section 1.704-2(g). This Section 5.03(b) is intended to be a minimum gain chargeback provision that complies with the requirements of Treasury Regulations Section 1.704-2(f), and shall be interpreted in a manner consistent therewith.

(c) If any Partner that unexpectedly receives an adjustment, allocation or Distribution described in Treasury Regulations Section 1.704-1(b)(2)(ii)(d)(4), (5) and (6) has an Adjusted Capital Account Deficit as of the end of any Taxable Year or other Fiscal Period, computed after the application of Section 5.03(a) and 5.03(b) but before the application of any other provision of this Article V, then items of income and gain for such Taxable Year or other Fiscal Period shall be allocated to such Partner in proportion to, and to the extent of, such Adjusted Capital Account Deficit. This Section 5.03(c) is intended to be a qualified income offset provision as described in Treasury Regulations Section 1.704-1(b)(2)(ii)(d) and shall be interpreted in a manner consistent therewith.

(d) If any Partner has a deficit Capital Account at the end of any Taxable Year or other Fiscal Period which is in excess of the sum of the amount such Partner is obligated to restore pursuant to the penultimate sentences of Regulations Sections 1.704-2(g)(1) and 1.704-2(i)(5), each such Partner shall be specially allocated items of Partnership income and gain in the amount of such excess as quickly as possible, provided that an allocation pursuant to this provision shall be made only if and to the extent that such Partner would have a deficit Capital Account in excess of such sum after all other allocations provided for in this Agreement have been made as if Section 5.03(c) and this Section 5.03(d) were not in the Agreement.

 

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(e) If the allocation of Losses or other items of loss or expense to a Partner as provided in Section 5.02 would create or increase an Adjusted Capital Account Deficit, there shall be allocated to such Partner only that amount of Losses (or other items of loss or expense) as will not create or increase an Adjusted Capital Account Deficit. The Losses that would, absent the application of the preceding sentence, otherwise be allocated to such Partner shall be allocated to the other Partners in accordance with their relative Percentage Interests, subject to this Section 5.03(e).

(f) Profits and Losses described in Section 5.01(b) shall be allocated in a manner consistent with the manner that the adjustments to the Capital Accounts are required to be made pursuant to Treasury Regulations Section 1.704-1(b)(2)(iv)(j) and (m).

(g) Simulated Depletion for each Depletable Property and Simulated Loss upon the disposition of a Depletable Property shall be allocated among the Partners in proportion to their shares of the Simulated Basis in such property.

(h) The allocations set forth in Section 5.03(a) through and including Section 5.03(e) (the “Regulatory Allocations”) are intended to comply with certain requirements of Sections 1.704-1(b) and 1.704-2 of the Treasury Regulations. The Regulatory Allocations may not be consistent with the manner in which the Partners intend to allocate Profit and Loss of the Partnership or make Distributions. Accordingly, notwithstanding the other provisions of this Article V, but subject to the Regulatory Allocations, income, gain, deduction and loss shall be reallocated among the Partners so as to eliminate the effect of the Regulatory Allocations and thereby cause the respective Capital Accounts of the Partners to be in the amounts (or as close thereto as possible) they would have been if Profit and Loss (and such other items of income, gain, deduction and loss) had been allocated without reference to the Regulatory Allocations. If in any Taxable Year or other Fiscal Period there is a decrease in Partnership Minimum Gain, or in Partner Minimum Gain, and application of the minimum gain chargeback requirements set forth in Section 5.03(a) or Section 5.03(b) would cause a distortion in the economic arrangement among the Partners, the Partners may, if they do not expect that the Partnership will have sufficient other income to correct such distortion, request the Internal Revenue Service to waive either or both of such minimum gain chargeback requirements. If such request is granted, this Agreement shall be applied in such instance as if it did not contain such minimum gain chargeback requirement.

(i) Consistent with the principles of Treasury Regulation Section 1.83-6(d), if any Partner (or its successor) transfers property (including cash) to any Partnership Employee or other service provider of the Partnership or any Subsidiary and such Partner is not entitled to be reimbursed by (or otherwise elects not to seek reimbursement from) the Partnership for the value of such property, then any items of deduction or loss resulting from or attributable to such transfer shall be allocated to the Partner (or its successor) that made such transfer and such Partner shall be deemed to have contributed such property to the Partnership pursuant to Section 3.12.

 

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(j) Notwithstanding any contrary provision in this Agreement except the foregoing provisions of Section 5.03, the General Partner shall make appropriate adjustments to allocations of Profits and Losses to (or, if necessary, allocate items of gross income, gain, loss or deduction of the Partnership among) the Partners upon the liquidation of the Partnership (within the meaning of Treasury Regulations Section 1.704-1(b)(2)(ii)(g)), the Transfer of substantially all the Units (whether by sale or exchange or merger) or sale of all or substantially all the assets of the Partnership, such that, to the maximum extent possible, the Capital Accounts of the Partners are proportionate to their Percentage Interests. In each case, such adjustments or allocations shall occur, to the maximum extent possible, in the Fiscal Year of the event requiring such adjustments or allocations.

Section 5.04 Tax Allocations.

(a) Subject to the remainder of this Section 5.04, the income, gains, losses, deductions and credits of the Partnership will be allocated, for U.S. federal (and applicable state and local) income tax purposes, among the Partners in accordance with the allocation of such income, gains, losses, deductions and credits among the Partners for computing their Capital Accounts; provided, that if any such allocation is not permitted by the Code or other applicable Law, the Partnership’s subsequent income, gains, losses, deductions and credits will be allocated among the Partners so as to reflect as nearly as possible the allocation set forth herein in computing their Capital Accounts.

(b) Cost and percentage depletion deductions with respect to each Depletable Property shall be computed separately by the Partners rather than the Partnership. For purposes of such computations, the U.S. federal income tax basis of each Depletable Property shall be allocated to each Partner in accordance with such Partner’s Percentage Interest as of the time such Depletable Property is acquired by the Partnership, and shall be reallocated among the Partners in accordance with such Partner’s Percentage Interest as determined immediately following the occurrence of an event giving rise to an adjustment to the Book Values of the Partnership’s Depletable Properties pursuant to the definition of Book Value (or at the time of any material additions to the U.S. federal income tax basis of such Depletable Property). The Partnership shall inform each Partner of such Partner’s allocable share of the U.S. federal income tax basis of each Depletable Property promptly following the acquisition of such Depletable Property by the Partnership, any adjustment resulting from expenditures required to be capitalized in such basis, and any reallocation of such basis as provided in the previous sentence. Such allocations are intended to be applied in accordance with the “partners’ interests in partnership capital” under Section 613A(c)(7)(D) of the Code; provided that the Partners understand and agree that the General Partner may authorize special allocations of tax basis, income, gain, deduction or loss, as computed for U.S. federal income tax purposes, in order to eliminate differences between Simulated Basis and adjusted U.S. federal income tax basis with respect to Depletable Properties, in such manner as determined consistent with the principles of Section 704(c) of the Code, the Treasury Regulations thereunder and the portions of the Treasury Regulations under Section 704(b) that apply the principles of Section 704(c), using the “remedial method”, as described in Treasury Regulations Section 1.704-3(d).

(c) For purposes of the separate computation of gain or loss by each Partner on a taxable Disposition of Depletable Property, the amount realized from such Disposition shall be allocated (i) first, to the Partners in an amount equal to the Simulated Basis in such Depletable Property and in the same proportion as their shares thereof were allocated and (ii) second, any

 

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remaining amount realized shall be allocated consistent with the allocation of Simulated Gains; provided, however, that the Partners understand and agree that the General Partner may authorize special allocations of tax basis, income, gain, deduction or loss, as computed for U.S. federal income tax purposes, in order to eliminate differences between Simulated Basis and adjusted U.S. federal income tax basis with respect to Depletable Properties, in such manner as determined consistent with the principles of Section 704(c) of the Code, the Treasury Regulations thereunder and the portions of the Treasury Regulations under Section 704(b) that apply the principles of Section 704(c), using the “remedial method”, as described in Treasury Regulations Section 1.704-3(d). The provisions of this Section 5.04(c) and the other provisions of this Agreement relating to allocations under Section 613A(c)(7)(D) of the Code are intended to comply with Treasury Regulations Section 1.704-1(b)(4)(v) and shall be interpreted and applied in a manner consistent with such Treasury Regulations.

(d) Each Partner shall, in a manner consistent with this Article V, separately keep records of its share of the adjusted tax basis in each Depletable Property, adjust such share of the adjusted tax basis for any cost or percentage depletion allowable with respect to such property and use such adjusted tax basis in the computation of its cost depletion or in the computation of its gain or loss on the disposition of such property by the Partnership. Upon the request of the Partnership, each Partner may advise the Partnership of its adjusted tax basis in each Depletable Property and any depletion computed with respect thereto, both as computed in accordance with the provisions of this subsection for purposes of allowing the Partnership to make adjustments to the tax basis of its assets as a result of certain transfers of interests in the Partnership or distributions by the Partnership. The Partnership may rely on such information and, if it is not provided by the Partner, may make such reasonable assumptions as it shall determine with respect thereto.

(e) Items of Partnership taxable income, gain, loss and deduction with respect to any property contributed to the capital of the Partnership shall be allocated among the Partners in accordance with Code Section 704(c) so as to take account of any variation between the adjusted basis of such property to the Partnership for U.S. federal income tax purposes and its Book Value using the “remedial method”, as described in Treasury Regulations Section 1.704-3(d).

(f) If the Book Value of any Partnership asset is adjusted pursuant to Section 5.01(b), subsequent allocations of items of taxable income, gain, loss and deduction with respect to such asset shall take account of any variation between the adjusted basis of such asset for U.S. federal income tax purposes and its Book Value in the same manner as under Code Section 704(c) using the “remedial method”, as described in Treasury Regulations Section 1.704-3(d).

(g) If, as a result of an exercise of a noncompensatory option (including the Warrants) to acquire an interest in the Partnership, a Capital Account reallocation is required under Treasury Regulations Section 1.704-1(b)(2)(iv)(s)(3), the Partnership shall make corrective allocations pursuant to Treasury Regulations Section 1.704-1(b)(4)(x) and 1.704-1(b)(4)(viii).

(h) Allocations of tax credits, tax credit recapture, and any items related thereto shall be allocated to the Partners pro rata as determined by the General Partner taking into account the principles of Treasury Regulations Section 1.704-1(b)(4)(ii).

 

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(i) For purposes of determining a Partner’s pro rata share of the Partnership’s “excess nonrecourse liabilities” within the meaning of Treasury Regulations Section 1.752-3(a)(3), each Partner’s interest in income and gain shall be in proportion to its Percentage Interests.

(j) Any recapture of depreciation or any other item of deduction shall be allocated, in accordance with Treasury Regulations Sections 1.1245-1(e) and 1.1254-5, to the Partners who received the benefit of such deductions to the maximum extent permissible by Law.

(k) Allocations pursuant to this Section 5.04 are solely for purposes of U.S. federal (and applicable state and local) income taxes and shall not affect, or in any way be taken into account in computing, any Partner’s Capital Account or share of Profits, Losses, Distributions or other Partnership items pursuant to any provision of this Agreement.

Section 5.05 Withholding; Indemnification and Reimbursement for Payments on Behalf of a Partner. The Partnership and its Subsidiaries may withhold from distributions, allocations or portions thereof if it is required to do so by any applicable Law, and each Partner hereby authorizes the Partnership and its Subsidiaries to withhold or pay on behalf of or with respect to such Partner any amount of U.S. federal, state, or local or non-U.S. taxes that the General Partner determines, in good faith, that the Partnership or any of its Subsidiaries is required to withhold or pay with respect to any amount distributable or allocable to such Partner pursuant to this Agreement. In addition, if the Partnership is obligated to pay any other amount to a Governmental Entity (or otherwise makes a payment to a Governmental Entity) that is specifically attributable to a Partner (including U.S. federal income taxes as a result of Partnership obligations pursuant to the Revised Partnership Audit Provisions with respect to items of income, gain, loss deduction or credit allocable or attributable to such Partner, state personal property taxes and state unincorporated business taxes, but excluding payments such as professional association fees and the like made voluntarily by the Partnership on behalf of any Partner based upon such Partner’s status as an employee of the Partnership), then such tax shall be treated as an amount of taxes withheld or paid with respect to such Partner pursuant to this Section 5.05. For all purposes under this Agreement, any amounts withheld or paid with respect to a Partner pursuant to this Section 5.05 shall be treated as having been distributed to such Partner at the time such withholding or payment is made. Further, to the extent that the cumulative amount of such withholding or payment for any period exceeds the distributions to which such Partner is entitled for such period, such Partner shall indemnify the Partnership in full for the amount of such excess. The General Partner may offset Distributions to which a Person is otherwise entitled under this Agreement against such Person’s obligation to indemnify the Partnership under this Section 5.05. A Partner’s obligation to indemnify the Partnership under this Section 5.05 shall survive the termination, dissolution, liquidation and winding up of the Partnership, and for purposes of this Section 5.05, the Partnership shall be treated as continuing in existence. The Partnership may pursue and enforce all rights and remedies it may have against each Partner under this Section 5.05, including instituting a lawsuit to collect amounts owed under such indemnity with interest accruing from the date such withholding or payment is made by the Partnership at a rate per annum equal to the sum of the Base Rate (but not in excess of the highest rate per annum permitted by Law). Any income from such indemnity (and interest) shall not be allocated to or distributed to the Partner paying such indemnity (and interest). Each Partner hereby agrees to furnish to the Partnership such information and forms as required or reasonably requested in order to comply with any laws and regulations governing withholding of tax or in order to claim any reduced rate of, or exemption from, withholding to which the Partner is legally entitled.

 

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Section 5.06 DPM Merger Agreement.

(a) As set forth in Section 1.7 of the DPM Merger Agreement , for U.S. federal and applicable state and local income tax purposes, the Partnership intends for the DPM Merger to qualify as an “assets-over” partnership merger transaction under Treasury Regulation Sections 1.708-1(c)(1) and 1.708-1(c)(3)(i), whereby the Partnership is intended to be the terminating partnership and DPM is intended to be the resulting partnership, and, as a result of such treatment, the DPM Merger shall be treated as a (i) contribution of all of the assets and liabilities of Partnership to DPM in exchange for partnership interests in DPM (the “Falcon OpCo Contribution”), immediately followed by a (ii) liquidating distribution by Partnership of such partnership interests to the partners of Partnership.

(b) Consistent with the foregoing,

(i) The initial Book Values of all properties of the Partnership contributed pursuant to the Falcon OpCo Contribution shall equal their Fair Market Values, and any forward Section 704(c) layer created in connection therewith shall, consistent with Section 5.04(e), be accounted for using the “remedial method” under Treasury Regulation Section 1.704-3(d),

(ii) the Capital Accounts of the DPM Holders will be “booked-up” in accordance with Treasury Regulation Section 1.704-1(b)(2)(iv)(f) to reflect their Fair Market Value, and any reverse Section 704(c) layer created in connection therewith shall, consistent with Section 5.04(f), be accounted for using the “remedial method” under Treasury Regulation Section 1.704-3(d), and

(iii) the Capital Account of each Limited Partner after giving effect to such adjustments shall be set forth on the Schedule of Limited Partners.

ARTICLE VI

MANAGEMENT

Section 6.01 Authority of General Partner.

(a) Except for situations in which the approval of any Limited Partner(s) is specifically required by this Agreement, (i) all management powers over the business and affairs of the Partnership shall be exclusively vested in the General Partner and (ii) the General Partner shall conduct, direct and exercise full control over all activities of the Partnership. Except as otherwise expressly provided for herein and subject to the other provisions of this Agreement, no Limited Partner has the right or power to participate in the management or affairs of the Partnership, nor does any Limited Partner have the power to sign for or bind the Partnership or deal with third parties on behalf of the Partnership without the consent of the General Partner.

 

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(b) The day-to-day business and operations of the Partnership shall be overseen and implemented by officers of the Partnership (each, an “Officer and collectively, the “Officers”), subject to the limitations imposed by the General Partner. An Officer may, but need not, be a Partner or an officer of the Corporation. Each Officer shall be appointed by the General Partner and shall hold office until his or her successor shall be duly designated and shall qualify or until his or her death or until he shall resign or shall have been removed in the manner hereinafter provided. Any one Person may hold more than one office. Subject to the other provisions in this Agreement (including in Section 6.06 below), the salaries or other compensation, if any, of the Officers of the Partnership shall be fixed from time to time by the General Partner. The authority and responsibility of the Officers shall include, but not be limited to, such duties as the General Partner may, from time to time, delegate to them and the carrying out of the Partnership’s business and affairs on a day-to-day basis. An Officer may also perform one or more roles as an officer of the General Partner. Subject to any agreement between the Corporation or the Partnership and an Officer regarding such Officer’s service or employment, the General Partner may remove any such Officer from office at any time, with or without cause. If any vacancy shall occur in any office, for any reason whatsoever, then the General Partner shall have the right to appoint a new Officer to fill the vacancy.

(c) Subject to law applicable to the Corporation and the Partnership, the General Partner shall have the power and authority to effectuate the sale, lease, transfer, exchange or other disposition of any, all or substantially all of the assets of the Partnership (including the exercise or grant of any conversion, option, privilege or subscription right or any other right available in connection with any assets at any time held by the Partnership) or the merger, consolidation, reorganization or other combination of the Partnership with or into another entity.

(d) Notwithstanding any other provision of this Agreement, neither the General Partner nor any Officer authorized by the General Partner shall have the authority, on behalf of the Partnership, either directly or indirectly, without the prior approval of each Partner, to take any action that would result in the failure of the Partnership to be taxable as a partnership for purposes of federal income tax, or take any position inconsistent with treating the Partnership as a partnership for purposes of federal income tax, except as required by Law.

Section 6.02 Actions of the General Partner. The General Partner may act through any Officer or through any other Person or Persons to whom authority and duties have been delegated pursuant to Section 6.06.

Section 6.03 Transfer and Withdrawal of General Partner.

(a) Except in connection with a General Partner Change of Control, the General Partner shall not have the right to transfer or assign the General Partner Interest, and the General Partner shall not have the right to withdraw from the Partnership; provided, that, without the consent of any of the Limited Partners, the General Partner may be reconstituted as or converted into a corporation, partnership or other form of entity (any such reconstituted or converted entity being deemed to be the General Partner for all purposes hereof) by merger, consolidation, conversion or otherwise, or transfer or assign the General Partner Interest (in whole or in part) to one of its Affiliates that is a wholly owned Subsidiary of the Corporation so long as such other entity or Affiliate shall have assumed in writing the obligations of the General Partner under this Agreement. In the event of an assignment or other transfer of all of the General Partner Interest in accordance with this Section 6.03, such assignee or transferee shall be substituted in the General

 

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Partner’s place as general partner of the Partnership in all respects under this Agreement and immediately thereafter the General Partner shall withdraw as a general partner of the Partnership (but shall remain entitled to exculpation and indemnification pursuant to Section 6.07 and Section 7.04 with respect to events occurring on or prior to such date).

(b) Except as otherwise contemplated by Section 6.03(a), no assignee or transferee shall become the general partner of the Partnership by virtue of such assignee’s or transferee’s receiving all or a portion of any interest in the Partnership from the General Partner or another assignee or transferee from the General Partner without the written consent of all of the Partners to such substitution, which consent may be given or withheld, or made subject to such conditions as each Partner deems appropriate in its sole discretion.

Section 6.04 Transactions Between Partnership and General Partner. The General Partner may cause the Partnership to contract and deal with the General Partner, or any Affiliate of the General Partner, or any Blackstone Party or Affiliate of any Blackstone Party, provided such contracts and dealings are on terms comparable to and competitive with those available to the Partnership from others dealing at arm’s length and are approved by (a) the Partners holding a majority of the Units (excluding Units held by the General Partner and its controlled Affiliates) then outstanding and (b) a majority of the Independent Directors, and, in each case, otherwise are permitted by the Credit Agreement.

Section 6.05 Reimbursement for Expenses. The Limited Partners acknowledge and agree that the General Partner is and will continue to be a wholly owned Subsidiary of the Corporation, whose Class A Common Stock is and will continue to be publicly traded, and therefore the General Partner and the Corporation will have access to the public capital markets and that such status and the services performed by the General Partner and the Corporation, if any, will inure to the benefit of the Partnership and all Limited Partners; therefore, the Partnership shall pay for and reimburse, without duplication, the General Partner and the Corporation amounts with respect to any fees, expenses and costs incurred by the General Partner, the Corporation or any other member of the Corporation Holdings Group on behalf of the Partnership, including all fees, expenses and costs of the Corporation being a public company (including public reporting obligations, proxy statements, stockholder meetings, stock exchange fees, transfer agent fees, SEC and FINRA filing fees and offering expenses) and maintaining its corporate existence, it being acknowledged and agreed that such payments and reimbursements shall not be treated as Distributions; provided, that the Partnership shall not pay or bear any income tax obligations of any member of the Corporation Holdings Group (but the Partnership shall be entitled to make distributions in respect of these obligations pursuant to Article IV). In the event that (a) shares of Class A Common Stock are sold to underwriters in any Public Offering at a price per share that is lower than the price per share for which such shares of Class A Common Stock are sold to the public in such Public Offering after taking into account any Discount and (b) the proceeds from such Public Offering are used to fund the Cash Election Amount for any Redeemed Units or otherwise contributed to the Partnership, the Partnership shall reimburse the applicable member(s) of the Corporation Holdings Group for such Discount by treating such Discount as an additional Capital Contribution made by such member(s) of the Corporation Holdings Group to the Company, issuing Common Units in respect of such deemed Capital Contribution in accordance with Section 11.01(i), and increasing the Capital Account of such member(s) of the Corporation Holdings Group by the amount of such Discount. To the extent practicable, expenses incurred by the General Partner, the Corporation or

 

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any other member of the Corporation Holdings Group on behalf of or for the benefit of the Partnership shall be billed directly to and paid by the Partnership. If and to the extent any advances or reimbursements to the General Partner, the Corporation or any other member of the Corporation Holdings Group by the Partnership pursuant to this Section 6.05 constitute gross income to such Person (as opposed to the repayment of advances made by such Person on behalf of the Partnership), such amounts shall be treated as “guaranteed payments” within the meaning of Code Section 707(c) and shall not be treated as distributions for purposes of computing the Limited Partners’ Capital Accounts.

Section 6.06 Delegation of Authority. The General Partner (a) may, from time to time, delegate to one or more Persons such authority and duties as the General Partner may deem advisable, and (b) may assign titles (including chief executive officer, president, chief executive officer, chief financial officers, chief operating officer, vice president, secretary, assistant secretary, treasurer or assistant treasurer) and delegate certain authority and duties to such Persons as the same may be amended, restated or otherwise modified from time to time, in each case subject to the terms of this Agreement. Any number of titles may be held by the same individual. The salaries or other compensation, if any, of such agents of the Partnership shall be fixed from time to time by the General Partner, subject to the other provisions in this Agreement.

Section 6.07 Limitation of Liability of the General Partner.

(a) Except as otherwise provided herein or in an agreement entered into by such Person and the Partnership, neither the General Partner nor any of the General Partner’s Affiliates shall be liable to the Partnership or to any Partner that is not the General Partner, in such Partner’s capacity as a partner of the Partnership, for any act or omission performed or omitted by the General Partner in its capacity as the general partner of the Partnership pursuant to authority granted to the General Partner by this Agreement; provided, however, that, except as otherwise provided herein, such limitation of liability shall not apply to the extent the act or omission was attributable to the General Partner’s bad faith, willful misconduct or violation of Law in which the General Partner acted with knowledge that its conduct was unlawful. The General Partner may exercise any of the powers granted to it by this Agreement and perform any of the duties imposed upon it hereunder either directly or by or through its agents, and shall not be responsible for any misconduct or negligence on the part of any such agent (so long as such agent was selected in good faith and with reasonable care). The General Partner shall be entitled to rely upon the advice of legal counsel, independent public accountants and other experts, including financial advisors, and any act of or failure to act by the General Partner in good faith reliance on such advice shall in no event subject the General Partner to liability to the Partnership or any Partner that is not the General Partner.

(b) Whenever this Agreement or any other agreement contemplated herein provides that the General Partner shall act in a manner which is, or provide terms which are, “fair and reasonable” to the Partnership or any Partner that is not the General Partner, the General Partner shall determine such appropriate action or provide such terms considering, in each case, the relative interests of each party to such agreement, transaction or situation and the benefits and burdens relating to such interests, any customary or accepted industry practices, and any applicable United States generally accepted accounting practices or principles.

 

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(c) Whenever in this Agreement or any other agreement contemplated herein, the General Partner is permitted or required to take any action or to make a decision in its “sole discretion” with “complete discretion” or under a grant of similar authority or latitude, the General Partner shall be entitled to consider such interests and factors as it desires, including its own interests, and shall, to the fullest extent permitted by applicable Law, have no duty or obligation to give any consideration to any interest of or factors affecting the Partnership or other Partners.

(d) Whenever in this Agreement the General Partner is permitted or required to take any action or to make a decision in its “reasonable discretion,” “good faith” or under another express standard, the General Partner shall act under such express standard and, to the fullest extent permitted by applicable Law, shall not be subject to any other or different standards imposed by this Agreement or any other agreement contemplated herein, and, notwithstanding anything contained herein to the contrary, so long as the General Partner acts in good faith, the resolution, action or terms so made, taken or provided by the General Partner shall not constitute a breach of this Agreement or any other agreement contemplated herein or impose liability upon the General Partner or any of the General Partner’s Affiliates.

Section 6.08 Investment Company Act. The General Partner shall use its best efforts to ensure that the Partnership shall not be subject to registration as an investment company pursuant to the Investment Company Act.

Section 6.09 Outside Activities of the Corporation and the General Partner. The Corporation shall not, and shall not cause or permit the General Partner to, directly or indirectly, enter into or conduct any business or operations, other than, as applicable, in connection with (a) the ownership, acquisition and disposition of Common Units, (b) the management of the business and affairs of the Partnership and its Subsidiaries, (c) the operation of the Corporation as a reporting company with a class (or classes) of securities registered under Section 12 of the Exchange Act and listed on a securities exchange, (d) the offering, sale, syndication, private placement or public offering of stock, bonds, securities or other interests, (e) financing or refinancing of any type related to the Partnership, its Subsidiaries or their assets or activities, and (f) such activities as are incidental to the foregoing; provided, however, that, except as otherwise provided herein, the net proceeds of any sale of Equity Securities of the Corporation pursuant to the preceding clauses (d) and (e) shall be made available to the Partnership as Capital Contributions and the proceeds of any other financing raised by the Corporation pursuant to the preceding clauses (d) and (e) shall be made available to the Partnership as loans or otherwise as appropriate and, provided further, that the Corporation may, in its sole and absolute discretion, from time to time hold or acquire assets in its own name or otherwise other than through the Partnership and its Subsidiaries so long as the Corporation takes all necessary measures to ensure that the economic benefits and burdens of such assets are otherwise vested in the Partnership or its Subsidiaries, through assignment, mortgage loan or otherwise. Nothing contained herein shall be deemed to prohibit the General Partner from executing any guarantee of indebtedness of the Partnership or its Subsidiaries.

Section 6.10 Standard of Care. Except to the extent otherwise expressly set forth in this Agreement, the General Partner shall, in connection with the performance of its duties in its capacity as the General Partner, have the same fiduciary duties to the Partnership and the Partners as would be owed to a Delaware corporation and its stockholders by its directors, and shall be

 

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entitled to the benefit of the same presumptions in carrying out such duties as would be afforded to a director of a Delaware corporation (as such duties and presumptions are defined, described and explained under the Laws of the State of Delaware as in effect from time to time). The provisions of this Agreement, to the extent that they restrict or eliminate the duties (including fiduciary duties) and liabilities of the General Partner otherwise existing at law or in equity, are agreed by the Partners to replace, to the fullest extent permitted by applicable Law, such other duties and liabilities of the General Partner.

ARTICLE VII

RIGHTS AND OBLIGATIONS OF PARTNERS

Section 7.01 Limitation of Liability and Duties of Partners; Investment Opportunities.

(a) Except as provided in this Agreement or in the Delaware Act, no Partner (including the General Partner) shall be obligated personally for any debt, obligation or liability solely by reason of being a Partner or acting as the General Partner of the Partnership; provided that, in the case of the General Partner, this sentence shall not in any manner limit the liability of any Partner to the Partnership or any other Partner attributable to a breach by the such Partner of any terms of this Agreement. Notwithstanding anything contained herein to the contrary, the failure of the Partnership to observe any formalities or requirements relating to the exercise of its powers or management of its business and affairs under this Agreement or the Delaware Act shall not be grounds for imposing personal liability on the Partners for liabilities of the Partnership.

(b) In accordance with the Delaware Act and the laws of the State of Delaware, a Partner may, under certain circumstances, be required to return amounts previously distributed to such Partner. It is the intent of the Partners that no Distribution to any Partner pursuant to Article IV shall be deemed a return of money or other property paid or distributed in violation of the Delaware Act. The payment of any such money or Distribution of any such property to a Partner shall be deemed to be a compromise within the meaning of Section 17-502(b) of the Delaware Act, and, to the fullest extent permitted by Law, any Partner receiving any such money or property shall not be required to return any such money or property to the Partnership or any other Person. However, if any court of competent jurisdiction holds that, notwithstanding the provisions of this Agreement, any Partner is obligated to make any such payment, such obligation shall be the obligation of such Partner and not of any other Partner.

(c) Notwithstanding any other provision of this Agreement (subject to Section 6.07 and except as set forth in Section 6.10, in each case with respect to the General Partner), to the extent that, at law or in equity, any Partner (or such Partner’s Affiliate or any manager, managing member, general partner, director, officer, employee, agent, fiduciary or trustee of such Partner or of any Affiliate of such Partner (each Person described in this parenthetical, a “Related Person”)) has duties (including fiduciary duties) to the Partnership, to another Partner (including the General Partner), to any Person who acquires an interest in a Limited Partner Interest or to any other Person bound by this Agreement, but in in each case other than any duties (including fiduciary duties) owed the Corporation and its stockholders, all such duties (including fiduciary duties) are hereby eliminated, to the fullest extent permitted by law, and replaced with the duties or standards expressly set forth herein, if any. Such elimination of duties (including fiduciary duties) to the Partnership, each of the Partners (including the General Partner),

 

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each other Person who acquires an interest in a Limited Partner Interest and each other Person bound by this Agreement and replacement thereof with the duties or standards expressly set forth herein, if any, are approved by the Partnership, each of the Partners (including the General Partner), each other Person who acquires an interest in a Limited Partner Interest and each other Person bound by this Agreement.

(d) Notwithstanding any duty (including any fiduciary duty) otherwise applicable at law or in equity, the doctrine of corporate opportunity, or any analogous doctrine, will not apply to any Partner (including the General Partner) or to any Related Person of such Partner, and no Partner (or any Related Person of such Partner) that acquires knowledge of a potential transaction, agreement, arrangement or other matter that may be an opportunity for the Partnership or the Partners will have any duty to communicate or offer such opportunity to the Partnership or the Partners, or to develop any particular investment, and such Person will not be liable to the Partnership or the Partners for breach of any fiduciary or other duty by reason of the fact that such Person pursues or acquires for, or directs such opportunity to, another Person or does not communicate such investment opportunity to the Partners. Notwithstanding any duty (including any fiduciary duty) otherwise applicable at law or in equity, neither the Partnership nor any Partner has any rights or obligations by virtue of this Agreement or the relationships created hereby in or to such independent ventures or the income or profits or losses derived therefrom, and the pursuit of any such ventures outside the Partnership, even if competitive with the activities of the Partnership or the Partners, will not be deemed wrongful or improper.

Section 7.02 Lack of Authority. No Partner, other than the General Partner or a duly appointed Officer, in each case in its capacity as such, has the authority or power to act for or on behalf of the Partnership, to do any act that would be binding on the Partnership or to make any expenditure on behalf of the Partnership. The Partners hereby consent to the exercise by the General Partner of the powers conferred on them by Law and this Agreement.

Section 7.03 No Right of Partition. No Partner, other than the General Partner, shall have the right to seek or obtain partition by court decree or operation of Law of any Partnership property, or the right to own or use particular or individual assets of the Partnership.

Section 7.04 Indemnification.

(a) Subject to Section 5.05, the Partnership hereby agrees to indemnify and hold harmless any Person (each an “Indemnified Person”) to the fullest extent permitted under the Delaware Act, as the same now exists or may hereafter be amended, substituted or replaced (but, in the case of any such amendment, substitution or replacement only to the extent that such amendment, substitution or replacement permits the Partnership to provide broader indemnification rights than the Partnership is providing immediately prior to such amendment), against all expenses, liabilities and losses (including attorneys’ fees, judgments, fines, excise taxes or penalties) reasonably incurred or suffered by such Person (or one or more of such Person’s Affiliates) by reason of the fact that such Person is or was a Partner or is or was serving as the General Partner, Officer, employee or other agent of the Partnership or is or was serving at the request of the Partnership as a manager, officer, director, principal, member, employee or agent of another corporation, partnership, joint venture, limited liability company, trust or other enterprise; provided, however, that no Indemnified Person shall be indemnified for any expenses, liabilities

 

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and losses suffered that are attributable to such Indemnified Person’s or its Affiliates’ bad faith, willful misconduct or violation of Law in which such Indemnified Person acted with knowledge that its conduct was unlawful, or for any present or future breaches of any representations, warranties, covenants or obligations by such Indemnified Person or its Affiliates contained herein or in the other agreements with the Partnership. Expenses, including attorneys’ fees, incurred by any such Indemnified Person in defending a proceeding shall be paid by the Partnership in advance of the final disposition of such proceeding, including any appeal therefrom, upon receipt of an undertaking by or on behalf of such Indemnified Person to repay such amount if it shall ultimately be determined that such Indemnified Person is not entitled to be indemnified by the Partnership.

(b) The right to indemnification and the advancement of expenses conferred in this Section 7.04 shall not be exclusive of any other right which any Person may have or hereafter acquire under any statute, agreement, bylaw, action by the General Partner or otherwise.

(c) The Partnership shall maintain directors’ and officers’ liability insurance, or substantially equivalent insurance, at its expense, to protect any Indemnified Person against any expense, liability or loss described in Section 7.04(a) whether or not the Partnership would have the power to indemnify such Indemnified Person against such expense, liability or loss under the provisions of this Section 7.04. The Partnership shall use its commercially reasonable efforts to purchase and maintain property, casualty and liability insurance in types and at levels customary for companies of similar size engaged in similar lines of business, as determined in good faith by the General Partner.

(d) If this Section 7.04 or any portion hereof shall be invalidated on any ground by any court of competent jurisdiction, then the Partnership shall nevertheless indemnify and hold harmless each Indemnified Person pursuant to this Section 7.04 to the fullest extent permitted by any applicable portion of this Section 7.04 that shall not have been invalidated and to the fullest extent permitted by applicable Law.

Section 7.05 Limited Partners Right to Act. For matters that require the approval of the Limited Partners, the Limited Partners shall act through meetings and written consents as described in paragraphs (a) and (b) below:

(a) Except as otherwise expressly provided by this Agreement, acts by the Limited Partners holding a majority of the outstanding Units, voting together as a single class, shall be the acts of the Limited Partners. Any Limited Partner entitled to vote at a meeting of Limited Partners may authorize another person or persons to act for it by proxy. An electronic mail, telegram, telex, cablegram or similar transmission by the Limited Partner, or a photographic, photostatic, facsimile or similar reproduction of a writing executed by the Limited Partner shall (if stated thereon) be treated as a proxy executed in writing for purposes of this Section 7.05(a). No proxy shall be voted or acted upon after eleven months from the date thereof, unless the proxy provides for a longer period. A proxy shall be revocable unless the proxy form conspicuously states that the proxy is irrevocable and that the proxy is coupled with an interest. Should a proxy designate two or more Persons to act as proxies, unless that instrument shall provide to the contrary, a majority of such Persons present at any meeting at which their powers thereunder are to be exercised shall have and may exercise all the powers of voting or giving consents thereby conferred, or, if only one be present, then such powers may be exercised by that one; or, if an even number attend and a majority do not agree on any particular issue, the Partnership shall not be required to recognize such proxy with respect to such issue if such proxy does not specify how the votes that are the subject of such proxy are to be voted with respect to such issue.

 

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(b) The actions by the Limited Partners permitted hereunder may be taken at a meeting called by the General Partner or by the Limited Partners holding a majority of the Units entitled to vote on such matter on at least 48 hours’ prior written notice to the other Limited Partners entitled to vote, which notice shall state the purpose or purposes for which such meeting is being called. The actions taken by the Limited Partners entitled to vote or consent at any meeting (as opposed to by written consent), however called and noticed, shall be as valid as though taken at a meeting duly held after regular call and notice if (but not until), either before, at or after the meeting, the Limited Partners entitled to vote or consent as to whom it was improperly held signs a written waiver of notice or a consent to the holding of such meeting or an approval of the minutes thereof. The actions by the Limited Partners entitled to vote or consent may be taken by vote of the Limited Partners entitled to vote or consent at a meeting or by written consent, so long as such consent is signed by Limited Partners having not less than the minimum number of Units that would be necessary to authorize or take such action at a meeting at which all Limited Partners entitled to vote thereon were present and voted. Prompt notice of the action so taken, which shall state the purpose or purposes for which such consent is required and may be delivered via email, without a meeting shall be given to those Limited Partners entitled to vote or consent who have not consented in writing; provided, however, that the failure to give any such notice shall not affect the validity of the action taken by such written consent. Any action taken pursuant to such written consent of the Limited Partners shall have the same force and effect as if taken by the Limited Partners at a meeting thereof.

Section 7.06 Inspection Rights. The Partnership shall permit each Partner and each of its designated representatives to visit and inspect (a) the books and records of the Partnership, including its partner ledger and a list of its Partners and (b) the books and records of its Subsidiaries. The Partners have no other inspection rights.

ARTICLE VIII

BOOKS, RECORDS, ACCOUNTING AND REPORTS

Section 8.01 Records and Accounting. The Partnership shall keep, or cause to be kept, appropriate books and records with respect to the Partnership’s business, including all books and records necessary to provide any information, lists and copies of documents required to be provided pursuant to Section 8.03 or pursuant to applicable Laws. All matters concerning (a) the determination of the relative amount of allocations and Distributions among the Limited Partners pursuant to Articles III and IV and (b) accounting procedures and determinations, and other determinations not specifically and expressly provided for by the terms of this Agreement, shall be determined by the General Partner, whose determination shall be final and conclusive as to all of the Limited Partners absent manifest clerical error.

Section 8.02 Fiscal Year. The Fiscal Year of the Partnership shall end on December 31 of each year or such other date as may be established by the General Partner; provided that the Partnership shall have the same Fiscal Year for accounting purposes as its Taxable Year for U.S. federal income tax purposes.

 

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Section 8.03 Reports. The Partnership shall deliver or cause to be delivered, within ninety (90) days after the end of each Fiscal Year, to each Person who was a Partner at any time during such Fiscal Year, all information reasonably necessary for the preparation of such Person’s United States federal and applicable state income tax returns.

ARTICLE IX

TAX MATTERS

Section 9.01 Preparation of Tax Returns. The General Partner shall arrange, at the Partnership’s expense, for the preparation and timely filing of all tax returns required to be filed by the Partnership. On or before March 15, June 15, September 15, and December 15 of each Taxable Year, the Partnership shall send to each Person who was a Partner at any time during the prior quarter, an estimate of such Partner’s state tax apportionment information and allocations to the Partners of taxable income, gains, losses, deductions and credits for the prior quarter, which estimate shall have been reviewed by the Partnership’s outside tax accountants. In addition, no later than the later of (a) March 15 following the end of the prior Taxable Year, and (b) thirty (30) Business Days after the issuance of the final financial statement report for a Fiscal Year by the Partnership’s auditors but in no event later than March 31 following the end of the prior Taxable Year, the Partnership shall send to each Person who was a Partner at any time during such Taxable Year, a statement showing such Partner’s (i) final state tax apportionment information, (ii) allocations to the Partners of taxable income, gains, losses, deductions and credits for such Taxable Year, (iii) a completed IRS Schedule K-1 and (iv) all other information reasonably requested and necessary for the preparation of such Partner’s U.S. federal (and applicable state and local) income tax returns, provided that the General Partner shall cause the Partnership to provide each Partner a draft IRS Schedule K-1 for the relevant Taxable Year no later than forty-five (45) days following the end of such Taxable Year. Each Partner shall notify the Partnership, and the Partnership shall take reasonable efforts to notify each of the other Partners, upon receipt of any notice of tax examination of the Partnership by U.S. federal, state or local authorities. Subject to the terms and conditions of this Agreement, in its capacity as Partnership Representative (as applicable), the General Partner shall have the authority to prepare the tax returns of the Partnership using the elections set forth in Section 9.02 and such other permissible methods and elections as it determines in its reasonable discretion.

Section 9.02 Tax Elections. The Partnership and any eligible Subsidiary shall make an election pursuant to Section 754 of the Code, shall not thereafter revoke such election. In addition, the Partnership (and any eligible Subsidiary) shall make the following elections on the appropriate forms or tax returns:

(a) to adopt the calendar year as the Partnership’s Taxable Year, if permitted under the Code;

(b) to adopt the accrual method of accounting for U.S. federal income tax purposes; and

(c) to elect to amortize the organizational expenses of the Partnership as permitted by Code Section 709(b).

 

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Each Partner will upon request supply any information reasonably necessary to give proper effect to any such elections.

Section 9.03 Tax Controversies. The General Partner shall be designated and may, on behalf of the Partnership, at any time, and without further notice to or consent from any Partner, act as the “partnership representative” of the Partnership, within the meaning given to such term in Section 6223 of the Code, and any corresponding or similar role for relevant state and local tax purposes (the General Partner, in such capacity, the “Partnership Representative”). The Partnership Representative shall have the right and obligation to take all actions authorized and required, respectively, by the Code or any applicable state or local Law with respect to Taxes for the Partnership Representative, and is authorized and required to represent the Partnership (at the Partnership’s expense) in connection with all examinations of the Partnership’s affairs by tax authorities, including resulting administrative and judicial proceedings, and to expend Partnership funds for professional services reasonably incurred in connection therewith. Unless the Limited Partners otherwise provide prior written consent, the Partnership Representative shall make the election to apply the “alternative to payment of imputed underpayment by partnership” under Section 6226 of the Code (and any similar provision of state or local law) to pass the underpayment adjustment of the Partnership to any partners of the reviewed year with respect to any taxable year ending on or before the date of the DPM Closing. Each Partner agrees to cooperate with the Partnership Representative and to do or refrain from doing any or all things reasonably requested by the Partnership Representative with respect to the conduct of such proceedings; provided that no Partner will be required to file an amended tax return or information statement for a prior taxable period pursuant to Section 6225(c)(2) of the Code (or any similar provision of state or local law) without the consent of such Partner. The Partnership Representative shall keep all Partners fully advised on a current basis of any contacts by or discussions with the tax authorities.

ARTICLE X

RESTRICTIONS ON TRANSFER OF UNITS

Section 10.01 Transfers by Partners. No holder of Units may Transfer any interest in any Units, except Transfers (a) pursuant to and in accordance with Section 10.02 or (b) approved in writing by the General Partner. Notwithstanding the foregoing, this Article X shall not apply to any Redemption or Call Right pursuant to Section 11.01.

Section 10.02 Permitted Transfers. The restrictions contained in Section 10.01 shall not apply to any Transfer (each, a “Permitted Transfer”) (a) by a Limited Partner to a Controlled Affiliate of such Limited Partner, (b) by a Royal Contributor to the direct holders of equity interests in such Royal Contributor, and if any such holder as of August 23, 2018 is a Blackstone Party, to the direct holders of equity interests in such Blackstone Party as of August 23, 2018, (c) by KMF DPM HoldCo, LLC or Chambers DPM HoldCo, LLC to the direct holders of equity interests in such Person, and if any such holder as of the date hereof is a Kimmeridge Party, to the direct holders of equity interests in such Kimmeridge Party, (d) by Rock Ridge Ridge Royalty Company LLC to the direct holders of its equity interests, and if any such holder as of the date hereof is a Blackstone Party, to the direct holders of equity interests in such Blackstone Party, (e) by Source Energy Leasehold, LP or Permian Mineral Acquisitions, LP to the direct holders of equity interests in such Person, and if any such holder as of the date hereof is a Source Party, to the direct holders of equity interests in such Source Party (f) to an Affiliate of, or a direct holder of equity interests

 

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in, Royal LP, (g) by any individual transferee pursuant to clauses (b) through (f) of this sentence to any Controlled Affiliate of such transferee or any trust, family partnership or family limited liability company, the sole beneficiaries, partners or members of which are such transferee or Relatives of such transferee for bona fide estate planning purposes, (h) to an Affiliate of any Blackstone Party, Kimmeridge Party or Source Party, (i) in the case of an individual Partner, upon death or incapacity to such Partner’s estate, executors, trustees, administrators and personal representatives, and then to such Partner’s legal representatives, heirs, beneficiaries or legatees (whether or not such recipients are a spouse, children, spouses of children, grandchildren, spouses of grandchildren, parents or siblings of such Partner) or (j) pursuant to a Redemption or Call Right in accordance with Article XI hereof; provided, however, that (i) the restrictions contained in this Agreement will continue to apply to Units after any Permitted Transfer of such Units and (ii) in the case of the foregoing clauses, the transferees of the Units so Transferred shall agree in writing to be bound by the provisions of this Agreement, and the transferor will deliver a written notice to the Partnership and the Partners, which notice will disclose in reasonable detail the identity of the proposed transferee. In the case of a Permitted Transfer (other than a Redemption or Call Right) by any Limited Partner (other than the Corporation) of Common Units to a transferee in accordance with this Section 10.02, such Limited Partner (or any subsequent transferee of such Limited Partner) shall be required to also transfer a number of shares of Class C Common Stock corresponding to the number of such Limited Partner’s (or subsequent transferee’s) Common Units that were transferred in the transaction to such transferee; and, in the case of a Redemption or Call Right, a number of shares of Class C Common Stock owned by such Limited Partner corresponding to the number of such Limited Partner’s Common Units that were transferred in such Redemption or Call Right shall be surrendered by such Limited Partner to the Corporation and cancelled by the Corporation. All Permitted Transfers are subject to the additional limitations set forth in Section 10.07(b).

Section 10.03 Restricted Units Legend. The Units have not been registered under the Securities Act and, therefore, in addition to the other restrictions on Transfer contained in this Agreement, cannot be sold unless subsequently registered under the Securities Act or an exemption from such registration is then available. To the extent such Units have been certificated, each certificate evidencing Units and each certificate issued in exchange for or upon the Transfer of any Units (if such securities remain Units as defined herein after such Transfer) shall be stamped or otherwise imprinted with a legend in substantially the following form:

“THE SECURITIES REPRESENTED BY THIS CERTIFICATE WERE ORIGINALLY ISSUED ON JUNE 7, 2022, AND HAVE NOT BEEN REGISTERED UNDER THE SECURITIES ACT OF 1933, AS AMENDED (THE “ACT”), AND MAY NOT BE SOLD OR TRANSFERRED IN THE ABSENCE OF AN EFFECTIVE REGISTRATION STATEMENT UNDER THE ACT OR AN EXEMPTION FROM REGISTRATION THEREUNDER. THE SECURITIES REPRESENTED BY THIS CERTIFICATE ARE ALSO SUBJECT TO ADDITIONAL RESTRICTIONS ON TRANSFER SPECIFIED IN THE SECOND AMENDED AND RESTATED AGREEMENT OF LIMITED PARTNERSHIP OF SITIO ROYALTIES OPERATING PARTNERSHIP, LP, AS MAY BE AMENDED AND MODIFIED FROM TIME TO TIME, AND SITIO ROYALTIES OPERATING PARTNERSHIP, LP RESERVES THE RIGHT TO REFUSE THE TRANSFER OF SUCH SECURITIES UNTIL SUCH

 

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CONDITIONS HAVE BEEN FULFILLED WITH RESPECT TO ANY TRANSFER. A COPY OF SUCH CONDITIONS SHALL BE FURNISHED BY SITIO ROYALTIES OPERATING PARTNERSHIP, LP TO THE HOLDER HEREOF UPON WRITTEN REQUEST AND WITHOUT CHARGE.”

The Partnership shall imprint such legend on certificates (if any) evidencing Units.

Section 10.04 Transfer. Prior to Transferring any Units (other than (a) in connection with a Redemption or Call Right in accordance with Article XI or (b) pursuant to a Change of Control Transaction), the Transferring holder of Units shall cause the prospective transferee to be bound by this Agreement and any other agreements executed by the holders of Units and relating to such Units in the aggregate (collectively, the “Other Agreements”), and shall cause the prospective transferee to execute and deliver to the Partnership and the other holders of Units a Joinder (or other counterpart to this Agreement acceptable to the General Partner) and counterparts of any applicable Other Agreements. Any Transfer or attempted Transfer of any Units in violation of any provision of this Agreement (including any prohibited indirect Transfers) (i) shall be void, and (ii) the Partnership shall not record such Transfer on its books or treat any purported transferee of such Units as the owner of such securities for any purpose.

Section 10.05 Assignees Rights.

(a) The Transfer of a Limited Partner Interest in accordance with this Agreement shall be effective as of the date of its assignment (assuming compliance with all of the conditions to such Transfer set forth herein), and such Transfer shall be shown on the books and records of the Partnership. Profits, Losses and other Partnership items shall be allocated between the transferor and the Assignee according to Code Section 706, using any permissible method as determined in the reasonable discretion of the General Partner. Distributions made before the effective date of such Transfer shall be paid to the transferor, and Distributions made after such date shall be paid to the Assignee.

(b) Unless and until an Assignee becomes a Limited Partner pursuant to Article XII, the Assignee shall not be entitled to any of the rights granted to a Limited Partner hereunder or under applicable Law, other than the rights granted specifically to Assignees pursuant to this Agreement; provided, however, that, without relieving the transferring Limited Partner from any such limitations or obligations as more fully described in Section 10.06, such Assignee shall be bound by any limitations and obligations of a Limited Partner contained herein that a Limited Partner would be bound on account of the Assignee’s Limited Partner Interest (including the obligation to make Capital Contributions on account of such Limited Partner Interest).

Section 10.06 Assignors Rights and Obligations. Any Limited Partner who shall Transfer any Limited Partner Interest in a manner in accordance with this Agreement shall cease to be a Limited Partner with respect to such Units or other interest and shall no longer have any rights or privileges, or, except as set forth in this Section 10.06, duties, liabilities or obligations, of a Limited Partner with respect to such Units or other interest (it being understood, however, that the applicable provisions of Section 6.07, Section 7.01 and Section 7.04 shall continue to inure to such Person’s benefit and such Person shall continue to be obligated to indemnify the Partnership for any obligations under Section 5.05), except that unless and until the Assignee (if not already a

 

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Limited Partner) is admitted as a Substituted Limited Partner in accordance with the provisions of Article XII (the “Admission Date”), (a) such assigning Limited Partner shall retain all of the duties, liabilities and obligations of a Limited Partner with respect to such Units or other interest, and (b) the General Partner may, in its sole discretion, reinstate all or any portion of the rights and privileges of such Limited Partner with respect to such Units or other interest for any period of time prior to the Admission Date. Nothing contained herein shall relieve any Limited Partner who Transfers any Units or other interest in the Partnership from any liability of such Limited Partner to the Partnership with respect to such Limited Partner Interest that may exist on the Admission Date or that is otherwise specified in the Delaware Act and incorporated into this Agreement or for any liability to the Partnership or any other Person for any materially false statement made by such Limited Partner (in its capacity as such) or for any present or future breaches of any representations, warranties or covenants by such Limited Partner (in its capacity as such) contained herein or in the other agreements with the Partnership.

Section 10.07 Overriding Provisions.

(a) Any Transfer of any Limited Partner Interest in violation of this Article X shall be null and void ab initio, and the provisions of Section 10.05 and 10.06 shall not apply to any such Transfers. Any Person to whom a Transfer of such Limited Partner Interest is made or attempted in violation of this Article X shall not become a Limited Partner with respect to such Limited Partner Interest, shall not be entitled to vote such Limited Partner Interest on any matters coming before the Limited Partners and shall not have any other rights in or with respect to such Limited Partner Interest. The General Partner shall promptly amend the Schedule of Limited Partners to reflect any Permitted Transfer pursuant to this Article X.

(b) Notwithstanding anything contained herein to the contrary (including the provisions of Section 10.01 and Article XI and Article XII), in no event shall any Limited Partner Transfer any Units to the extent such Transfer would:

(i) result in the violation of the Securities Act, or any other applicable U.S. federal or state or non-U.S. Laws;

(ii) subject the Partnership to registration as an investment company under the Investment Company Act;

(iii) in the reasonable determination of the General Partner, be a violation of or a default (or an event that, with notice or the lapse of time or both, would constitute a default) under, or result in an acceleration of any indebtedness under, any promissory note, mortgage, loan agreement, indenture or similar instrument or agreement to which the Partnership or the General Partner is a party;

(iv) cause the Partnership to lose its status as a partnership for U.S. federal income tax purposes or, without limiting the generality of the foregoing, cause the Partnership to be treated as a “publicly traded partnership” or to be taxed as a corporation pursuant to Section 7704 of the Code and any applicable Treasury Regulations issued thereunder, or any successor provision of the Code;

 

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(v) be a Transfer to a Person who is not legally competent or who has not achieved his or her majority under applicable Law (excluding trusts for the benefit of minors); or

(vi) result in the Partnership having more than one hundred (100) partners, within the meaning of Treasury Regulations Section 1.7704-1(h)(1) (determined pursuant to the rules of Treasury Regulations Section 1.7704-1(h)(3)).

ARTICLE XI

REDEMPTION AND EXCHANGE RIGHTS

Section 11.01 Redemption Right of a Limited Partner.

(a) Each Limited Partner other than the Corporation Holdings Group shall be entitled from time to time to cause the Partnership to redeem all or a portion of such Limited Partner’s Common Units (such Partner a “Redeeming Partner”), together with an equal number of shares of Class C Common Stock, in exchange for shares of Class A Common Stock or, at the Partnership’s election under certain circumstances, cash in accordance with Section 11.01(d) (referred to herein as the “Redemption Right”), upon the terms and subject to the conditions set forth in this Section 11.01 and subject to the Corporation’s (or such designated member(s) of the Corporation Holdings Group’s) Call Right as set forth in Section 11.01(m).

(b) In order to exercise its Redemption Right, each Redeeming Partner shall provide written notice in a reasonable form as the Partnership may provide from time to time (the “Redemption Notice”) to the Partnership and the Corporation, on or before any Redemption Notice Date, stating that the Redeeming Partner elects to have redeemed on the next Redemption Date a stated number of Units, together with an equal number shares of Class C Common Stock. Upon delivery of any Redemption Notice by any Redeeming Partner on or before any Redemption Notice Date, such Limited Partner may not revoke or rescind such Redemption Notice after such Redemption Notice Date. Any Redemption Notice delivered for a Redemption on a Regular Redemption Date may not be contingent. Any Redemption Notice delivered for a Redemption on a Special Redemption Date may be made contingent on the consummation of the Registered Offering or other transaction described in the notice of the General Partner specifying such Special Redemption Date. Any notice by any Limited Partner pursuant to the Royal Registration Rights Agreement or the DPM Registration Rights Agreement to demand or participate in any Registered Offering shall be deemed to constitute a Redemption Notice for the related Special Redemption Date with respect to the Units to be sold in such Registered Offering.

(c) On any Redemption Date for which any Limited Partner delivered a Redemption Notice with respect to Units, unless the Partnership elects to pay cash in accordance with Section 11.01(d) or the Corporation (or such designated member(s) of the Corporation Holdings Group) exercises its Call Right pursuant to Section 11.01(m), on such Redemption Date such number of Units, together with an equal number of shares of Class C Common Stock, shall be redeemed for an equal number of shares of Class A Common Stock.

(d) The Partnership shall be entitled to elect to settle any Redemption by delivering to the Redeeming Partner, in lieu of the applicable number of shares of Class A Common Stock that would be received in such Redemption, an amount of cash equal to the Cash Election Amount for such shares.

 

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  (e)

Subject to Section 11.01(f), each Limited Partner’s Redemption Right shall be subject to the following limitations and qualifications:

 

  (i)

except as provided herein, Redemptions shall only be permitted on each Redemption Date;

 

  (ii)

a Redeeming Partner, excluding any Limited Partners prior to the Effective Date and any of their transferees in accordance with this Agreement (other than the Blackstone Parties and any of their transferees), shall only be permitted to redeem less than all of its Units if (A) after such Redemption it would continue to hold at least 1,607,010 Units and (B) it redeems not less than 1,607,010 Units in such Redemption; provided that the amount of Units held or redeemed in the preceeding clauses (A) and (B) shall be deemed to include all Units held or redeemed by (x) all other Blackstone Parties, if such Redeeming Partner is a Blackstone Party, (y) all other Kimmeridge Parties, if such Redeeming Partner is a Kimmeridge Party, and (z) all other Source Parties, if such Redeeming Partner is a Source Party; and

 

  (iii)

any Redemption of Units issued after the date hereof (other than in connection with any recapitalization), including such Units issued to Limited Partners as of the date hereof, may be limited in accordance with the terms of any agreements or instruments entered into in connection with such issuance, as deemed necessary or desirable in the discretion of the General Partner.

(f) The General Partner may impose additional limitations and restrictions on Redemptions (including limiting Redemptions or creating priority procedures for Redemptions), to the extent it determines, in good faith, such limitations and restrictions to be necessary or appropriate to avoid undue risk that the Partnership may be classified as a “publicly traded partnership” within the meaning of Section 7704 of the Code. Furthermore, the General Partner may require any Limited Partner or group of Limited Partners to redeem all of their Units to the extent it determines, that such Redemption is necessary or appropriate to avoid undue risk that the Partnership may be classified as a “publicly traded partnership” within the meaning of Section 7704 of the Code. Upon delivery of any notice by the General Partner to such Limited Partner or group of Limited Partners requiring such Redemption, such Limited Partner or group of Limited Partners shall exchange, subject to exercise by the Corporation of the Call Right pursuant to Section 11.01(m), all of their Units effective as of the date specified in such notice (and such date shall be deemed to be a Redemption Date for purposes of this Agreement) in accordance with this Section 11.01 and otherwise in accordance with the requirements set forth in such notice.

 

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(g) For U.S. federal income (and applicable state and local) tax purposes, each of the Redeeming Partner, the Partnership and the Corporation (and any other member of the Corporation Holdings Group), as the case may be, agree to treat each Redemption and, if the Corporation (or another member of the Corporation Holdings Group) exercises its Call Right, each transaction between the redeeming or selling Limited Partner and the Corporation (or such other member of the Corporation Holdings Group), as a sale of such Partner’s Units (together, if applicable, with the same number of shares of Class C Common Stock) to the Corporation (or such other member of the Corporation Holdings Group) in exchange for shares of Class A Common Stock or cash, as applicable.

(h) Each Redemption shall be deemed to have been effected on the applicable Redemption Date. Any Limited Partner redeeming Units in accordance with this Agreement may request that the shares of Class A Common Stock to be issued upon such Redemption be issued in a name other than such Limited Partner. Any Person or Persons in whose name or names any shares of Class A Common Stock are issuable on any Redemption Date shall be deemed to have become, on such Redemption Date, the holder or holders of record of such shares.

(i) Unless a member of the Corporation Holdings Group has elected its Call Right pursuant to Section 11.01(m) with respect to any Redemption, on the relevant Redemption Date and immediately prior to such Redemption, (i) the Corporation (or such other member(s) of the Corporation Holdings Group) shall contribute to the Partnership the consideration the Redeeming Partner is entitled to receive under Section 11.01(c) (including in the event the Partnership exercises its right to deliver the Cash Election Amount pursuant to Section 11.01(d)) and the Partnership shall issue to the Corporation (or such other member(s) of the Corporation Holdings Group) a number of Units or, pursuant to Section 3.04(a), other Equity Securities of the Partnership as consideration for such contribution, (ii) the Partnership shall (A) cancel the redeemed Units and (B) transfer to the Redeeming Partner the consideration the Redeeming Partner is entitled to receive under Section 11.01(c) (including in the event the Partnership exercises its right to deliver the Cash Election Amount pursuant to Section 11.01(d)), and (iii) the Corporation shall cancel the surrendered shares of Class C Common Stock, if applicable. Notwithstanding any other provisions of this Agreement to the contrary, in the event that the Partnership makes a Cash Election that is funded with proceeds from a Public Offering of the Corporation’s Equity Securities, the Corporation Holdings Group shall only be obligated to contribute to the Partnership an amount in cash equal to the net proceeds (after deduction of any underwriters’ discounts or commissions and brokers’ fees or commissions (including, for the avoidance of doubt, any deferred discounts or commissions and brokers’ fees or commissions payable in connection with or as a result of such Public Offering)) (such difference, the “Discount”) from the sale by the Corporation of a number of shares of Class A Common Stock equal to the number of Units and, if applicable, shares of Class C Common Stock to be redeemed with such cash or from the sale of other Equity Securities of the Corporation used to fund the Cash Election Amount; provided that the Corporation’s Capital Account (or the Capital Account(s) of the other member(s) of the Corporation Holdings Group, as applicable) shall be increased by the amount of such Discount in accordance with Section 6.05; provided further, that the contribution of such net proceeds shall in no event affect the Redeeming Partner’s right to receive the Cash Election Amount.

(j) If (i) there is any reclassification, reorganization, recapitalization or other similar transaction pursuant to which the shares of Class A Common Stock are converted or changed into another security, securities or other property (other than as a result of a subdivision or combination or any transaction subject to Section 3.04(b) or Section 3.04(c)), or (ii) except in connection with actions taken with respect to the capitalization of the Corporation or the Partnership pursuant to

 

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Section 3.04(d), the Corporation, by dividend or otherwise, distributes to all holders of the shares of Class A Common Stock evidences of its indebtedness or assets, including securities (including shares of Class A Common Stock and any rights, options or warrants to all holders of the shares of Class A Common Stock to subscribe for or to purchase or to otherwise acquire shares of Class A Common Stock, or other securities or rights convertible into, redeemable for or exercisable for shares of Class A Common Stock) but excluding (A) any cash dividend or distribution or (B) any such distribution of indebtedness or assets, in either case (A) or (B) received by the Corporation, directly or indirectly, from the Partnership in respect of the Units, then upon any subsequent Redemption, in addition to the shares of Class A Common Stock or the Cash Election Amount, as applicable, each Redeeming Partner shall be entitled to receive the amount of such security, securities or other property that such Limited Partner would have received if such Redemption had occurred immediately prior to the effective date of such reclassification, reorganization, recapitalization, other similar transaction, dividend or other distribution, taking into account any adjustment as a result of any subdivision (by any split, distribution or dividend, reclassification, reorganization, recapitalization or otherwise) or combination (by reverse split, reclassification, recapitalization or otherwise) of such security, securities or other property that occurs after the effective time of such reclassification, reorganization, recapitalization or other similar transaction. For the avoidance of doubt, if there is any reclassification, reorganization, recapitalization or other similar transaction in which the shares of Class A Common Stock are converted or changed into another security, securities or other property, or any dividend or distribution (other than an excluded dividend or distribution, as described above in clause (A) or (B)), this Section 11.01 shall continue to be applicable, mutatis mutandis, with respect to such security or other property.

(k) The Corporation shall at all times keep available, solely for the purpose of issuance upon a Redemption, out of its authorized but unissued shares of Class A Common Stock, such number of shares of Class A Common Stock that shall be issuable upon the Redemption of all outstanding Units (other than those Units held by any member of the Corporation Holdings Group); provided, that nothing contained herein shall be construed to preclude the Corporation from satisfying its obligations with respect to a Redemption by delivery of cash pursuant to a Cash Election or shares of Class A Common Stock that are held in the treasury of the Corporation. The Corporation covenants that all shares of Class A Common Stock that shall be issued upon a Redemption shall, upon issuance thereof, be validly issued, fully paid and non-assessable. In addition, for so long as the shares of Class A Common Stock are listed on a national securities exchange, the Corporation shall use its reasonable best efforts to cause all shares of Class A Common Stock issued upon a Redemption to be listed on such national securities exchange at the time of such issuance.

(l) The issuance of shares of Class A Common Stock upon a Redemption shall be made without charge to the Redeeming Partner for any stamp or other similar tax in respect of such issuance, except that if any such shares of Class A Common Stock are to be issued in a name other than that of the Redeeming Partner, then the Person or Persons in whose names such shares are to be issued shall pay to the Corporation the amount of any tax payable in respect of any Transfer involved in such issuance or establish to the satisfaction of the Corporation that such tax has been paid or is not payable. Each of the Partnership and the Corporation shall be entitled to deduct and withhold from any consideration payable or otherwise deliverable upon a Redemption (and the Redeeming Partner agrees to indemnify the Partnership and the Corporation with respect to) such amounts as may be required to be deducted or withheld therefrom under the Code or any provision

 

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of applicable Law, and to the extent deduction and withholding is required, such deduction and withholding may be taken in shares of Class A Common Stock. Prior to making such deduction or withholding, the Partnership shall give written notice to the Redeeming Partner and reasonably cooperate with such Redeeming Partner to reduce or avoid any such withholding. To the extent such amounts are so deducted or withheld and paid over to the relevant Governmental Entity, such amounts shall be treated for all purposes under this Agreement as having been paid to the Redeeming Partner, and, if withholding is taken in shares of Class A Common Stock, the relevant withholding party shall be treated as having sold such shares of Class A Common Stock on behalf of such Redeeming Partner for an amount of cash equal to the Fair Market Value thereof at the time of such deemed sale and paid such cash proceeds to the appropriate Governmental Entity.

(m) Notwithstanding anything to the contrary in this Section 11.01, a Redeeming Partner shall be deemed to have offered to sell its Units as described in any Redemption Notice to each member of the Corporation Holdings Group, and the Corporation (or such other member(s) of the Corporation Holdings Group designated by the Corporation) may, in its sole discretion, in accordance with this Section 11.01(m), elect to purchase directly and acquire such Units on the Redemption Date by paying to the Redeeming Partner that number of shares of Class A Common Stock the Redeeming Partner would otherwise receive pursuant to Section 11.01(c) or, if the Corporation (or such designated member(s) of the Corporation Holdings Group) makes a Cash Election, the Cash Election Amount for such shares of Class A Common Stock (the “Call Right”), whereupon the Corporation (or such designated member(s) of the Corporation Holdings Group) shall acquire the Units offered for redemption by the Redeeming Partner and shall be treated thereafter for all purposes of this Agreement as the owner of such Units.

(n) In the event that (i) the Limited Partners (other than any member of the Corporation Holdings Group) beneficially own, in the aggregate, less than 10% of the then-outstanding Units and (ii) the shares of Class A Common Stock are listed or admitted to trading on a national securities exchange, the General Partner shall have the right, in its sole discretion, to require any Limited Partner (other than any member of the Corporation Holdings Group), collectively with its Affiliates, that beneficially owns less than 5% of the then-outstanding Units to effect a Redemption of all of such Limited Partner’s Units (together with the surrender and delivery of the same number of shares of Class C Common Stock); provided that a Cash Election shall not be permitted pursuant to such a Redemption under this Section 11.01(n). The Corporation shall deliver written notice to the Partnership and any such Limited Partner of its intention to exercise its Redemption Right pursuant to this Section 11.01(n) (a “Minority Partner Redemption Notice”) at least five (5) Business Days prior to the proposed date upon which such Redemption is to be effected (such proposed date, the “Minority Partner Redemption Date”), indicating in such notice the number of Units (and corresponding shares of Class C Common Stock) held by such Limited Partner that the Corporation intends to require to be subject to such Redemption. Any Redemption pursuant to this Section 11.01(n) shall be effective on the Minority Partner Redemption Date. From and after the Minority Partner Redemption Date, (x) the Units and shares of Class C Common Stock subject to such Redemption shall be deemed to be Transferred to the Corporation on the Minority Partner Redemption Date and (y) such Limited Partner shall cease to have any rights with respect to the Units and shares of Class C Common Stock subject to such Redemption (other than the right to receive shares of Class A Common Stock pursuant to such Redemption). Following delivery of a Minority Partner Redemption Notice and on or prior to the Minority Partner Redemption Date, the Limited Partners shall take all actions reasonably requested by the Corporation to effect such Redemption, including taking any action and delivering any document required pursuant to the remainder of this Section 11.01 to effect a Redemption.

 

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(o) No Redemption shall impair the right of the Redeeming Partner to receive any distributions payable on the Units redeemed pursuant to such Redemption in respect of a record date that occurs prior to the Redemption Date for such Redemption. No Redeeming Partner, or a Person designated by a Redeeming Partner to receive shares of Class A Common Stock, shall be entitled to receive, with respect to such record date, distributions or dividends both on Units redeemed by the Partnership from such Redeeming Partner and on shares of Class A Common Stock received by such Redeeming Partner, or other Person so designated, if applicable, in such Redemption.

(p) In connection with a General Partner Change of Control, the Corporation shall have the right, in its sole discretion, to require each Limited Partner (other than any member of the Corporation Holdings Group) to effect a Redemption of all of such Limited Partner’s Units and the corresponding number of shares of Class C Common Stock. Any Redemption pursuant to this Section 11.01(p) shall be effective immediately prior to and conditioned upon the consummation of the General Partner Change of Control (the “Change of Control Exchange Date”). From and after the Change of Control Exchange Date, (i) the Common Units and the shares of Class C Common Stock subject to such Redemption shall be deemed to be transferred to the Corporation on the Change of Control Exchange Date and (ii) such Limited Partner shall cease to have any rights with respect to the Units and shares of Class C Common Stock subject to such Redemption (other than the right to receive shares of Class A Common Stock pursuant to such Redemption). The Corporation shall provide written notice of an expected General Partner Change of Control to all Partners within the earlier of (x) five (5) Business Days following the execution of the agreement with respect to such General Partner Change of Control and (y) ten (10) Business Days before the proposed date upon which the contemplated General Partner Change of Control is to be effected, indicating in such notice such information as may reasonably describe the General Partner Change of Control transaction, subject to applicable Law, including the date of execution of such agreement or such proposed effective date, as applicable, the amount and types of consideration to be paid for shares of Class A Common Stock in the General Partner Change of Control, any election with respect to types of consideration that a holder of shares of Class A Common Stock, as applicable, shall be entitled to make in connection with such General Partner Change of Control, and the number of Common Units and the corresponding shares of Class C Common Stock held by such Limited Partner that the Corporation intends to require to be subject to such Redemption. Following delivery of such notice and on or prior to the Change of Control Exchange Date, the Limited Partners shall take all actions reasonably requested by the Corporation to effect such Redemption, including taking any action and delivering any document required pursuant to the remainder of this Section 11.01(p) to effect a Redemption. Nothing contained in this Section 11.01(p) shall limit the right of any Limited Partner to vote for or participate in any proposed Change of Control Transaction of the Corporation with respect to such Limited Partner’s Units and shares of Class C Common Stock or exchange all Units of such Limited Partner for shares of Class A Common Stock in connection with such Change of Control Transaction.

 

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ARTICLE XII

ADMISSION OF LIMITED PARTNERS

Section 12.01 Substituted Limited Partners. Subject to the provisions of Article X, in connection with the Permitted Transfer of a Limited Partner Interest hereunder, the transferee shall become a substituted Limited Partner (“Substituted Limited Partner”) on the effective date of such Transfer, which effective date shall not be earlier than the date of compliance with the conditions to such Transfer, and such admission shall be shown on the books and records of the Partnership.

Section 12.02 Additional Limited Partners. Subject to the provisions of Article III and Article X, any Person may be admitted to the Partnership as an additional Limited Partner (any such Person, an “Additional Limited Partner”) only upon furnishing to the General Partner (a) a Joinder (or other counterpart to this Agreement acceptable to the General Partner) and counterparts of any applicable Other Agreements and (b) such other documents or instruments as may be reasonably necessary or appropriate to effect such Person’s admission as a Limited Partner (including entering into such documents as the General Partner may deem appropriate in its reasonable discretion). Such admission shall become effective on the date on which the General Partner determines in its reasonable discretion that such conditions have been satisfied and when any such admission is shown on the books and records of the Partnership.

ARTICLE XIII

WITHDRAWAL AND RESIGNATION; TERMINATION OF RIGHTS

Section 13.01 Withdrawal and Resignation of Limited Partners. No Limited Partner shall have the power or right to withdraw or otherwise resign as a Limited Partner from the Partnership prior to the dissolution and winding up of the Partnership pursuant to Article XIV. Any Limited Partner, however, that attempts to withdraw or otherwise resign as a Limited Partner from the Partnership without the prior written consent of the General Partner upon or following the dissolution and winding up of the Partnership pursuant to Article XIV, but prior to such Limited Partner receiving the full amount of Distributions from the Partnership to which such Limited Partner is entitled pursuant to Article XIV, shall be liable to the Partnership for all damages (including all lost profits and special, indirect and consequential damages) directly or indirectly caused by the withdrawal or resignation of such Partner. Upon a Transfer of all of a Limited Partner’s Units in a Transfer permitted by this Agreement, subject to the provisions of Section 10.06, such Limited Partner shall cease to be a Partner.

ARTICLE XIV

DISSOLUTION AND LIQUIDATION

Section 14.01 Dissolution. The Partnership shall not be dissolved by the admission of Additional Limited Partners or Substituted Limited Partners or the attempted withdrawal or resignation of a Partner. The Partnership shall dissolve, and its affairs shall be wound up, upon:

(a) the unanimous decision of the General Partner together with all the Partners to dissolve the Partnership;

 

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(b) a Change of Control Transaction that is not approved by the Majority Partners;

(c) a dissolution of the Partnership under Section 17-801(4) of the Delaware Act; or

(d) the entry of a decree of judicial dissolution of the Partnership under Section 17-802 of the Delaware Act.

Except as otherwise set forth in this Article XIV, the Partnership is intended to have perpetual existence. An Event of Withdrawal shall not cause a dissolution of the Partnership and the Partnership shall continue in existence subject to the terms and conditions of this Agreement.

Section 14.02 Liquidation and Termination. On dissolution of the Partnership, the General Partner shall act as liquidator or may appoint one or more Persons as liquidator. The liquidators shall proceed diligently to wind up the affairs of the Partnership and make final distributions as provided herein and in the Delaware Act. The costs of liquidation shall be borne as a Partnership expense. Until final distribution, the liquidators shall continue to operate the Partnership properties with all of the power and authority of the General Partner. The steps to be accomplished by the liquidators are as follows:

(a) as promptly as possible after dissolution and again after final liquidation, the liquidators shall cause a proper accounting to be made by a recognized firm of certified public accountants of the Partnership’s assets, liabilities and operations through the last day of the calendar month in which the dissolution occurs or the final liquidation is completed, as applicable;

(b) the liquidators shall cause notice of liquidation to be mailed to each known creditor of and claimant against the Partnership;

(c) the liquidators shall pay, satisfy or discharge from Partnership funds, or otherwise make adequate provision for payment and discharge thereof (including the establishment of a cash fund for contingent liabilities in such amount and for such term as the liquidators may reasonably determine): first, all expenses incurred in liquidation; and second, all of the debts, liabilities and obligations of the Partnership; and

(d) all remaining assets of the Partnership shall be distributed to the Partners in accordance with Article IV by the end of the Taxable Year during which the liquidation of the Partnership occurs (or, if later, by ninety (90) days after the date of the liquidation). The distribution of cash and/or property to the Partners in accordance with the provisions of this Section 14.02 and Section 14.03 below constitutes a complete return to the Partners of their Capital Contributions, a complete distribution to the Partners of their interest in the Partnership and all the Partnership’s property and constitutes a compromise to which all Partners have consented within the meaning of the Delaware Act. To the extent that a Partner returns funds to the Partnership, it has no claim against any other Partner for those funds. In no event shall a Limited Partner be entitled to exercise any Redemption Rights, and no Redemptions shall be effected, on or after the earlier of the record date for and the effective date of the distribution of cash and/or property to the Partners in accordance with the provisions of this Section 14.02 and Section 14.03.

 

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Section 14.03 Deferment; Distribution in Kind. Notwithstanding the provisions of Section 14.02, but subject to the order of priorities set forth therein, if upon dissolution of the Partnership the liquidators determine that an immediate sale of part or all of the Partnership’s assets would be impractical or would cause undue loss (or would otherwise not be beneficial) to the Partners, the liquidators may, in their sole discretion, defer for a reasonable time the liquidation of any assets except those necessary to satisfy Partnership liabilities (other than loans to the Partnership by Partners) and reserves. Subject to the order of priorities set forth in Section 14.02, the liquidators may, in their sole discretion, distribute to the Partners, in lieu of cash, either (a) all or any portion of such remaining Partnership assets in-kind in accordance with the provisions of Section 14.02(d), (b) as tenants in common and in accordance with the provisions of Section 14.02(d), undivided interests in all or any portion of such Partnership assets or (c) a combination of the foregoing. Any such Distributions in kind shall be subject to (x) such conditions relating to the disposition and management of such assets as the liquidators deem reasonable and equitable and (y) the terms and conditions of any agreements governing such assets (or the operation thereof or the holders thereof) at such time. Any Partnership assets distributed in kind will first be written up or down to their Fair Market Value, thus creating Profit or Loss (if any), which shall be allocated in accordance with Article V. The liquidators shall determine the Fair Market Value of any property distributed in accordance with the valuation procedures set forth in Article XV.

Section 14.04 Cancellation of Certificate. On completion of the distribution of Partnership assets as provided herein, the Partnership is terminated (and the Partnership shall not be terminated prior to such time), and the General Partner (or such other Person or Persons as the Delaware Act may require or permit) shall file a certificate of cancellation with the Secretary of State of Delaware, cancel any other filings made pursuant to this Agreement that are or should be canceled and take such other actions as may be necessary to terminate the Partnership. The Partnership shall be deemed to continue in existence for all purposes of this Agreement until it is terminated pursuant to this Section 14.04.

Section 14.05 Reasonable Time for Winding Up. A reasonable time shall be allowed for the orderly winding up of the business and affairs of the Partnership and the liquidation of its assets pursuant to Sections 14.02 and 14.03 in order to minimize any losses otherwise attendant upon such winding up.

Section 14.06 Return of Capital. The liquidators shall not be personally liable for the return of Capital Contributions or any portion thereof to the Partners (it being understood that any such return shall be made solely from Partnership assets).

ARTICLE XV

VALUATION

Section 15.01 Determination. Fair Market Value of a specific Partnership asset will mean the amount which the Partnership would receive in an all-cash sale of such asset in an arms-length transaction with a willing unaffiliated third party, with neither party having any compulsion to buy or sell, consummated on the day immediately preceding the date on which the event occurred which necessitated the determination of the Fair Market Value (and after giving effect to any transfer taxes payable in connection with such sale), as such amount is determined by the General Partner (or, if pursuant to Section 14.02, the liquidators) in its good faith judgment using all factors, information and data it deems to be pertinent.

 

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Section 15.02 Dispute Resolution. If any Limited Partner or Limited Partners dispute the accuracy of any determination of Fair Market Value in accordance with Section 15.01, and the General Partner and such Limited Partner(s) are unable to agree on the determination of the Fair Market Value of any asset of the Partnership, the General Partner and such Limited Partner(s) shall each select a nationally recognized investment banking firm experienced in valuing securities of closely-held companies such as the Partnership in the Partnership’s industry (the “Appraisers”), who shall each determine the Fair Market Value of the asset or the Partnership (as applicable) in accordance with the provisions of Section 15.01. The Appraisers shall be instructed to give written notice of their determination of the Fair Market Value of the asset or the Partnership (as applicable) within thirty (30) days of their appointment as Appraisers. If Fair Market Value as determined by an Appraiser is higher than Fair Market Value as determined by the other Appraiser by 10% or more, and the General Partner and such Limited Partner(s) do not otherwise agree on a Fair Market Value, the original Appraisers shall designate a third Appraiser meeting the same criteria used to select the original two, and the Fair Market Value shall be the average of the Fair Market Values determined by all three Appraisers, unless the General Partner and such Limited Partner(s) otherwise agree on a Fair Market Value. If Fair Market Value as determined by an Appraiser is within 10% of the Fair Market Value as determined by the other Appraiser (but not identical), and the General Partner and such Limited Partner(s) do not otherwise agree on a Fair Market Value, the General Partner shall select the Fair Market Value of one of the Appraisers. The fees and expenses of the Appraisers shall be borne by the Partnership.

ARTICLE XVI

GENERAL PROVISIONS

Section 16.01 Power of Attorney.

(a) Each Limited Partner who is an individual hereby constitutes and appoints the General Partner (or the liquidator, if applicable) with full power of substitution, as his or her true and lawful agent and attorney-in-fact, with full power and authority in his, her or its name, place and stead, to:

(i) execute, swear to, acknowledge, deliver, file and record in the appropriate public offices (A) this Agreement, all certificates and other instruments and all amendments thereof which the General Partner deems appropriate or necessary to form, qualify, or continue the qualification of, the Partnership as a limited partnership in the State of Delaware and in all other jurisdictions in which the Partnership may conduct business or own property; (B) all instruments which the General Partner deems appropriate or necessary to reflect any amendment, change, modification or restatement of this Agreement in accordance with its terms; (C) all conveyances and other instruments or documents which the General Partner deems appropriate or necessary to reflect the dissolution and liquidation of the Partnership pursuant to the terms of this Agreement, including a certificate of cancellation; and (D) all instruments relating to the admission, withdrawal or substitution of any Partner pursuant to Article XII or Article XIII; and

 

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(ii) sign, execute, swear to and acknowledge all ballots, consents, approvals, waivers, certificates and other instruments appropriate or necessary, in the reasonable judgment of the General Partner, to evidence, confirm or ratify any vote, consent, approval, agreement or other action which is made or given by the Partners hereunder or is consistent with the terms of this Agreement, in the reasonable judgment of the General Partner, to effectuate the terms of this Agreement.

(b) The foregoing power of attorney is irrevocable and coupled with an interest, and shall survive the death, disability, incapacity, dissolution, bankruptcy, insolvency or termination of any Limited Partner who is an individual and the transfer of all or any portion of his, her or its Limited Partner Interest and shall extend to such Limited Partner’s heirs, successors, assigns and personal representatives.

Section 16.02 Confidentiality. Each of the Partners agree to hold the Partnership’s Confidential Information in confidence and may not use such information except in furtherance of the business of the Partnership or as otherwise authorized separately in writing by the General Partner. “Confidential Information as used herein includes, but is not limited to, ideas, financial product structuring, business strategies, innovations and materials, all aspects of the Partnership’s business plan, proposed operation and products, corporate structure, financial and organizational information, analyses, proposed partners, software code and system and product designs, employees and their identities, equity ownership, the methods and means by which the Partnership plans to conduct its business, all trade secrets, trademarks, tradenames and all intellectual property associated with the Partnership’s business, in each case obtained by a Partner from the Partnership or any of its Affiliates or representatives. With respect to any Partner, Confidential Information does not include information or material that: (a) is rightfully in the possession of such Partner at the time of disclosure by the Partnership; (b) before or after it has been disclosed to such Partner by the Partnership, becomes part of public knowledge, not as a result of any action or inaction of such Partner in violation of this Agreement; (c) is approved for release by written authorization of the Chief Executive Officer of the Partnership or of the Corporation; (d) is disclosed to such Partner or its representatives by a third party not, to the knowledge of such Partner, in violation of any obligation of confidentiality owed to the Partnership with respect to such information; or (e) is or becomes independently developed by such Partner or its representatives without use of or reference to the Confidential Information.

Section 16.03 Amendments. This Agreement may be amended or modified solely by the General Partner. Notwithstanding the foregoing, no amendment or modification (a) to this Section 16.03 may be made without the prior written consent of each of the Partners, (b) that modifies the limited liability of any Partner, or increases the liabilities or obligations of any Partner, in each case, may be made without the consent of each such affected Partner, (c) that materially alters or changes any rights, preferences or privileges of any Limited Partner Interests in a manner that is different or prejudicial relative to any other Limited Partner Interests, may be made without the approval of a majority in interest of the Partners holding the Limited Partner Interests affected in such a different or prejudicial manner (excluding any such Limited Partner Interests held by the General Partner or any Affiliates controlled by the General Partner), (d) that materially alters or changes any rights, preferences or privileges of a holder of any class of Limited Partner Interests in a manner that is different or prejudicial relative to any other holder of the same class of Limited Partner Interests, may be made without the approval of the holder of Limited

 

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Partner Interests affected in such a different or prejudicial manner, (e) that materially and adversely alters or changes any rights, preferences or privileges of a holder of the General Partner or the Corporation, may be made without the approval of a majority of the Independent Directors, (f) that materially and disproportionately adversely affects the holders of any Limited Partner Interests as compared to the Corporation or any of its controlled Affiliates holding Limited Partner Interests, without the approval of the Blackstone Parties for so long as the Blackstone Parties and their Affiliates in the aggregate own at least five percent (5)% of the outstanding Limited Partner Interests; and (g) to any of the terms and conditions of this Agreement which terms and conditions expressly require the approval or action of certain Persons may be made without obtaining the consent of the requisite number or specified percentage of such Persons who are entitled to approve or take action on such matter; provided, that the General Partner, acting alone, may amend this Agreement to reflect the issuance of additional Units or Equity Securities in accordance with Section 3.04.

Section 16.04 Title to Partnership Assets. Partnership assets shall be deemed to be owned by the Partnership as an entity, and no Partner, individually or collectively, shall have any ownership interest in such Partnership assets or any portion thereof. The Partnership shall hold title to all of its property in the name of the Partnership and not in the name of any Partner. All Partnership assets shall be recorded as the property of the Partnership on its books and records, irrespective of the name in which legal title to such Partnership assets is held. The Partnership’s credit and assets shall be used solely for the benefit of the Partnership, and no asset of the Partnership shall be transferred or encumbered for, or in payment of, any individual obligation of any Partner.

Section 16.05 Addresses and Notices. Any notice provided for in this Agreement will be in writing and will be either personally delivered, or received by certified mail, return receipt requested, or sent by reputable overnight courier service (charges prepaid) to the Partnership at the address set forth below and to any other recipient and to any Partner at such address as indicated by the Partnership’s records, or at such address or to the attention of such other person as the recipient party has specified by prior written notice to the sending party. Notices will be deemed to have been given hereunder when delivered personally or sent by telecopier (provided confirmation of transmission is received), three (3) days after deposit in the U.S. mail and one (1) day after deposit with a reputable overnight courier service. The Partnership’s address is:

Sitio Royalties Operating Partnership, LP

c/o Sitio Royalties Corp.,

1144 15th Street, Suite 2650

Denver, Colorado 80202

Section 16.06 Binding Effect; Intended Beneficiaries. This Agreement shall be binding upon and inure to the benefit of the parties hereto and their heirs, executors, administrators, successors, legal representatives and permitted assigns.

Section 16.07 Creditors. None of the provisions of this Agreement shall be for the benefit of or enforceable by any creditors of the Partnership or any of its Affiliates, and no creditor who makes a loan to the Partnership or any of its Affiliates may have or acquire (except pursuant to the terms of a separate agreement executed by the Partnership in favor of such creditor) at any time as a result of making the loan any direct or indirect interest in Partnership Profits, Losses, Distributions, capital or property other than as a secured creditor.

 

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Section 16.08 Waiver. No failure by any party to insist upon the strict performance of any covenant, duty, agreement or condition of this Agreement or to exercise any right or remedy consequent upon a breach thereof shall constitute a waiver of any such breach or any other covenant, duty, agreement or condition.

Section 16.09 Counterparts. This Agreement may be executed in separate counterparts, each of which will be an original and all of which together shall constitute one and the same agreement binding on all the parties hereto.

Section 16.10 Applicable Law. This Agreement shall be governed by, and construed in accordance with, the laws of the State of Delaware, without giving effect to any choice of law or conflict of law rules or provisions (whether of the State of Delaware or any other jurisdiction) that would cause the application of the laws of any jurisdiction other than the State of Delaware. Any dispute relating hereto shall be heard in the state or federal courts of the State of Delaware, and the parties agree to jurisdiction and venue therein.

Section 16.11 Severability. Whenever possible, each provision of this Agreement will be interpreted in such manner as to be effective and valid under applicable Law, but if any provision of this Agreement is held to be invalid, illegal or unenforceable in any respect under any applicable Law or rule in any jurisdiction, such invalidity, illegality or unenforceability will not affect any other provision or the effectiveness or validity of any provision in any other jurisdiction, and this Agreement will be reformed, construed and enforced in such jurisdiction as if such invalid, illegal or unenforceable provision had never been contained herein.

Section 16.12 Further Action. The parties shall execute and deliver all documents, provide all information and take or refrain from taking such actions as may be reasonably necessary or appropriate to achieve the purposes of this Agreement.

Section 16.13 Delivery by Electronic Transmission. This Agreement and any signed agreement or instrument entered into in connection with this Agreement or contemplated hereby, and any amendments hereto or thereto, to the extent signed and delivered by means of an electronic transmission, including by a facsimile machine or via email, shall be treated in all manner and respects as an original agreement or instrument and shall be considered to have the same binding legal effect as if it were the original signed version thereof delivered in person. At the request of any party hereto or to any such agreement or instrument, each other party hereto or thereto shall re-execute original forms thereof and deliver them to all other parties. No party hereto or to any such agreement or instrument shall raise the use of electronic transmission by a facsimile machine or via email to deliver a signature or the fact that any signature or agreement or instrument was transmitted or communicated through such electronic transmission as a defense to the formation of a contract and each such party forever waives any such defense.

 

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Section 16.14 Right of Offset. Whenever the Partnership is to pay any sum (other than pursuant to Article IV) to any Partner, any amounts that such Partner owes to the Partnership which are not the subject of a good faith dispute may be deducted from that sum before payment. The distribution of Units to the Corporation shall not be subject to this Section 16.14.

Section 16.15 Effectiveness. This Agreement shall be effective immediately upon the DPM Closing (the “Effective Time”). The Prior Limited Partnership Agreement shall govern the rights and obligations of the Partnership and the other parties to this Agreement in their capacity as Partners prior to the Effective Time.

Section 16.16 Entire Agreement. This Agreement and those documents expressly referred to herein (including the Royal Registration Rights Agreement, the DPM Registration Rights Agreement, the DPM Merger Agreement and the Contribution Agreement) embody the complete agreement and understanding among the parties and supersede and preempt any prior understandings, agreements or representations by or among the parties, written or oral, which may have related to the subject matter hereof in any way. For the avoidance of doubt, the Prior Limited Partnership Agreement is superseded by this Agreement as of the Effective Time and shall be of no further force and effect thereafter.

Section 16.17 Remedies. Each Partner shall have all rights and remedies set forth in this Agreement and all rights and remedies which such Person has been granted at any time under any other agreement or contract and all of the rights which such Person has under any Law. Any Person having any rights under any provision of this Agreement or any other agreements contemplated hereby shall be entitled to enforce such rights specifically (without posting a bond or other security), to recover damages by reason of any breach of any provision of this Agreement and to exercise all other rights granted by Law.

Section 16.18 Descriptive Headings; Interpretation. The descriptive headings of this Agreement are inserted for convenience only and do not constitute a substantive part of this Agreement. Whenever required by the context, any pronoun used in this Agreement shall include the corresponding masculine, feminine or neuter forms, and the singular form of nouns, pronouns and verbs shall include the plural and vice versa. The use of the word “including” in this Agreement shall be by way of example rather than by limitation. Reference to any agreement, document or instrument means such agreement, document or instrument as amended or otherwise modified from time to time in accordance with the terms thereof, and if applicable hereof. Without limiting the generality of the immediately preceding sentence, no amendment or other modification to any agreement, document or instrument that requires the consent of any Person pursuant to the terms of this Agreement or any other agreement will be given effect hereunder unless such Person has consented in writing to such amendment or modification. Wherever required by the context, references to a Fiscal Year shall refer to a portion thereof. The use of the words “or,” “either” and “any” shall not be exclusive. The parties hereto have participated jointly in the negotiation and drafting of this Agreement. In the event an ambiguity or question of intent or interpretation arises, this Agreement shall be construed as if drafted jointly by the parties hereto, and no presumption or burden of proof shall arise favoring or disfavoring any party by virtue of the authorship of any of the provisions of this Agreement. Wherever a conflict exists between this Agreement and any other agreement, this Agreement shall control but solely to the extent of such conflict.

[Signature Pages Follow]

 

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IN WITNESS WHEREOF, the undersigned have executed or caused to be executed on their behalf this Second Amended and Restated Agreement of Limited Partnership as of the date first written above.

 

GENERAL PARTNER:
SITIO ROYALTIES GP, LLC
By:   /s/ Brett S. Riesenfeld
Name:   Brett S. Riesenfeld
Title:   Executive Vice President, General Counsel and Secretary

[Signature Page to Second Amended and Restated Agreement of Limited Partnership]


LIMITED PARTNERS:
SITIO ROYALTIES CORP.
By:   /s/ Brett S. Riesenfeld
Name:   Brett S. Riesenfeld
Title:   Executive Vice President, General Counsel and Secretary
KMF DPM HOLDCO, LLC
By:   /s/ Noam Lockshin
Name:   Noam Lockshin
Title:   Manager
CHAMBERS DPM HOLDCO, LLC
By:   /s/ Noam Lockshin
Name:   Noam Lockshin
Title:   Manager
ROCK RIDGE ROYALTY COMPANY LLC
By:   /s/ M. Christopher Doyle
Name:   M. Christopher Doyle
Title:   President and CEO
ROYAL RESOURCES L.P.
By:   Royal Resources GP L.L.C., its general partner
By:   /s/ Erik Belz

Name:

  Erik Belz

Title:

  President

[Signature Page to Second Amended and Restated Agreement of Limited Partnership]


SOURCE ENERGY LEASEHOLD, LP
By: Source Energy Operating, LP, its general partner
By: Source Energy Manager, LLC, its sole member
By:   /s/ James Brandon Benson
Name:   James Brandon Benson
Title:   Authorized Person
PERMIAN MINERAL ACQUISITIONS, LP
By: Permian Mineral Acquisitions GP, LLC, its general partner
By:   /s/ James Brandon Benson
Name:   James Brandon Benson
Title:   Authorized Person

 

 

[Signature Page to Second Amended and Restated Agreement of Limited Partnership]


Christopher L. Conoscenti
By:  

/s/ Christopher L. Conoscenti

Carrie L. Osicka
By:  

/s/ Carrie L. Osicka

Britton L. James
By:  

/s/ Britton L. James

Jarret J. Marcoux
By:  

/s/ Jarret J. Marcoux

Brett S. Riesenfeld
By:  

/s/ Brett S. Riesenfeld

 

 

[Signature Page to Second Amended and Restated Agreement of Limited Partnership]


SCHEDULE 1*

SCHEDULE OF LIMITED PARTNERS

 

Partner

   Common
Units
     Percentage
Interest
    DPM
Closing
Capital
Account
Balance**
     Additional
Cash Capital
Contributions
     Additional
Non-Cash
Capital
Contributions
     Capital
Accounts
 

Sitio Royalties Corp.

     12,088,546        14.4184           

Arkoma Production Company of Texas, Inc.

     42,411        0.0506           

George H. Bishop

     196,451        0.2343           

HBC Promote LLC

     330,081        0.3937           

Margaret W. Molleston

     196,451        0.2343           

Noble Royalties Inc.

     14,037        0.0167           

Noble Royalties Holdings LP

     268,102        0.3198           

Royal Resources LP

     8,799,410        10.4954           

KMF DPM HoldCo, LLC

     32,298,535        38.5236           

Chambers DPM HoldCo, LLC

     4,196,985        5.0059           

Rock Ridge Royalty Company LLC

     12,165,172        14.5098           

Source Energy Leasehold, LP

     7,380,700        8.8032           

Permian Mineral Acquisitions, LP

     5,554,420        6.6250           

Christopher L. Conoscenti

     92,858        0.1108           

Carrie L. Osicka

     60,186        0.0718           

Britton L. James

     52,161        0.0622           

Jarret J. Marcoux

     52,161        0.0622           

Brett S. Riesenfeld

     52,161        0.0622           

 

*

This Schedule of Limited Partners shall be updated from time to time to reflect any adjustment with respect to any subdivision (by Unit split or otherwise) or any combination (by reverse Unit split or otherwise) of any outstanding Common Units, or to reflect any additional issuances of Common Units pursuant to this Agreement.

**

DPM Closing Capital Account Balances to be determined at a later date as necessary.

 

Schedule 1 – 1


EXHIBIT A

FORM OF JOINDER AGREEMENT

This JOINDER AGREEMENT, dated as of , 20        (this “Joinder”), is delivered pursuant to that certain Second Amended and Restated Agreement of Limited Partnership of Sitio Royalties Operating Partnership, LP (the “Partnership”), dated as of June 7, 2022 (as amended, restated, amended and restated, supplemented or otherwise modified from time to time, the “Partnership Agreement”). Capitalized terms used but not otherwise defined herein have the respective meanings set forth in the Partnership Agreement.

1. Joinder to the Partnership Agreement. Upon the execution of this Joinder by the undersigned and delivery hereof to the General Partner, the undersigned hereby is and hereafter will be a Limited Partner under the Partnership Agreement and a party thereto, with all the rights, privileges and responsibilities of a Limited Partner thereunder. The undersigned hereby agrees that it shall comply with and be fully bound by the terms of the Partnership Agreement as if it had been a signatory thereto as of the date thereof.

2. Incorporation by Reference. All terms and conditions of the Partnership Agreement are hereby incorporated by reference in this Joinder as if set forth herein in full.

3. Address. All notices under the Partnership Agreement to the undersigned shall be direct to:

[Name]

[Address]

[City, State, Zip Code]

Attn:

Facsimile:

E-mail:

IN WITNESS WHEREOF, the undersigned has duly executed and delivered this Joinder as of the day and year first above written.

 

[NAME OF NEW PARTNER]
By:    
Name:  
Title:  

Acknowledged and agreed

as of the date first set forth above:

 

SITIO ROYALTIES GP, LLC
By:    
Name:  
Title:  

 

 

A-1

Exhibit 10.4

Execution Version

SITIO ROYALTIES CORP.

LONG TERM INCENTIVE PLAN

1. Purpose. The purpose of the Sitio Royalties Corp. Long Term Incentive Plan (the “Plan”) is to provide a means through which (a) Sitio Royalties Corp., a Delaware corporation (the “Company”), and its Affiliates may attract, retain and motivate qualified persons as employees, directors and consultants, thereby enhancing the profitable growth of the Company and its Affiliates and (b) persons upon whom the responsibilities of the successful administration and management of the Company and its Affiliates rest, and whose present and potential contributions to the welfare of the Company and its Affiliates are of importance, can acquire and maintain stock ownership or awards the value of which is tied to the performance of the Company, thereby strengthening their concern for the welfare of the Company and its Affiliates. Accordingly, the Plan provides for the grant of Options, SARs, Restricted Stock, Restricted Stock Units, Stock Awards, Dividend Equivalents, Other Stock-Based Awards, Cash Awards, Substitute Awards, or any combination of the foregoing, as determined by the Committee in its sole discretion.

2. Definitions. For purposes of the Plan, the following terms shall be defined as set forth below:

(a) “Affiliate” means any corporation, partnership, limited liability company, limited liability partnership, association, trust or other organization that, directly or indirectly, controls, is controlled by, or is under common control with, the Company. For purposes of the preceding sentence, “control” (including, with correlative meanings, the terms “controlled by” and “under common control with”), as used with respect to any entity or organization, shall mean the possession, directly or indirectly, of the power (i) to vote more than 50% of the securities having ordinary voting power for the election of directors of the controlled entity or organization or (ii) to direct or cause the direction of the management and policies of the controlled entity or organization, whether through the ownership of voting securities, by contract, or otherwise.

(b) “ASC Topic 718” means the Financial Accounting Standards Board Accounting Standards Codification Topic 718, Compensation – Stock Compensation, as amended or any successor accounting standard.

(c) “Award” means any Option, SAR, Restricted Stock, Restricted Stock Unit, Stock Award, Dividend Equivalent, Other Stock-Based Award, Cash Award, or Substitute Award, together with any other right or interest, granted under the Plan.

(d) “Award Agreement” means any written instrument (including any employment, severance or change in control agreement) that sets forth the terms, conditions, restrictions and/or limitations applicable to an Award which may, in the discretion of the Company, be transmitted electronically to any Participant. Each Award Agreement shall be subject to the terms and conditions of the Plan.

(e) “Board” means the Board of Directors of the Company.

(f) “Cash Award” means an Award denominated in cash granted under Section 6(i).

 

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(g) “Change in Control” means, except as otherwise provided in an Award Agreement, the consummation of any of the following events after the Effective Date:

(i) any Person or any group of Persons acting together which would constitute a “group” for purposes of Section 13(d) of the Exchange Act (excluding a corporation or other entity owned, directly or indirectly, by the stockholders of the Company in substantially the same proportions as their ownership of stock of the Company) is or becomes the “beneficial owner,” as defined in Rule 13d-3 under the Exchange Act, directly or indirectly, of securities of the Company representing more than 50% of the combined voting power of the Company’s then outstanding voting securities;

(ii) individuals who constitute the Incumbent Board cease for any reason to constitute at least a majority of the Board;

(iii) there is consummated a merger or consolidation of the Company with any other corporation or other entity, and, immediately after the consummation of such merger or consolidation, the voting securities of the Company immediately prior to such merger or consolidation do not continue to represent or are not converted into more than 50% of the combined voting power of the then-outstanding voting securities of the Person resulting from such merger or consolidation or, if the surviving company is a subsidiary, the ultimate parent thereof; or

(iv) the stockholders of the Company approve a plan of complete liquidation or dissolution of the Company or there is consummated an agreement or series of related agreements for the sale or other disposition, directly or indirectly, by the Company of all or substantially all of the Company’s assets, other than such sale or other disposition by the Company of all or substantially all of the Company’s assets to an entity, at least 50% of the combined voting power of the voting securities of which are owned by stockholders of the Company in substantially the same proportions as their ownership of the Company immediately prior to such sale, provided that, in all such cases, the transactions contemplated by the provisions above are ultimately consummated.

Notwithstanding the foregoing, except with respect to clause (ii) above, a “Change in Control” shall not be deemed to have occurred by virtue of the consummation of any transaction or series of integrated transactions immediately following which the record holders of the shares of the Company immediately prior to such transaction or series of transactions continue to have substantially the same proportionate ownership in, and own substantially all of the shares of, an entity which owns, either directly or through a subsidiary, all or substantially all of the assets of the Company immediately following such transaction or series of transactions. Further notwithstanding the foregoing, with respect to an Award that provides for a deferral of compensation under the Nonqualified Deferred Compensation Rules and with respect to which a Change in Control would trigger settlement or payment of such Award, “Change in Control” shall mean an event that qualifies both as a “Change in Control” (as defined in this Section 2(g)) as well as a “change in control event” as defined in the Nonqualified Deferred Compensation Rules.

 

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(h) “Change in Control Price” means the amount determined in the following clause (i), (ii), (iii), (iv) or (v), whichever the Committee determines is applicable, as follows:

(i) the price per share offered to holders of Stock in any merger or consolidation, (ii) the per share Fair Market Value of the Stock immediately before the Change in Control or other event without regard to assets sold in the Change in Control or other event and assuming the Company has received the consideration paid for the assets in the case of a sale of the assets, (iii) the amount distributed per share of Stock in a dissolution transaction, (iv) the price per share offered to holders of Stock in any tender offer or exchange offer whereby a Change in Control or other event takes place, or (v) if such Change in Control or other event occurs other than pursuant to a transaction described in clauses (i), (ii), (iii), or (iv) of this Section 0, the value per share of the Stock that may otherwise be obtained with respect to such Awards or to which such Awards track, as determined by the Committee as of the date determined by the Committee to be the date of cancellation and surrender of such Awards. In the event that the consideration offered to stockholders of the Company in any transaction described in this Section 0 or in Section 8(e) consists of anything other than cash, the Committee shall determine the fair cash equivalent of the portion of the consideration offered which is other than cash and such determination shall be binding on all affected Participants to the extent applicable to Awards held by such Participants.

(i) “Code” means the Internal Revenue Code of 1986, as amended from time to time, including the guidance and regulations promulgated thereunder and successor provisions, guidance and regulations thereto.

(j) “Committee” means the Compensation Committee of the Board, unless no such Compensation Committee exists, in which case, a committee of two or more directors designated by the Board to administer the Plan; provided, however, that, unless otherwise determined by the Board, the Committee shall consist solely of two or more Qualified Members.

(k) “Dividend Equivalent” means a right, granted to an Eligible Person under Section 6(g), to receive cash, Stock, other Awards or other property equal in value to dividends paid with respect to a specified number of shares of Stock, or other periodic payments.

(l) “Effective Date” means June 7, 2022.

(m) “Eligible Person” means any individual who, as of the date of grant of an Award, is an officer or employee of the Company or of any of its Affiliates, and any other person who provides services to the Company or any of its Affiliates, including consultants and non-employee directors of the Company; provided, however, that, any such individual must be an “employee” of the Company or any of its parents or subsidiaries within the meaning of General Instruction A.1(a) to Form S-8 if such individual is granted an Award that may be settled in Stock. An employee on leave of absence may be an Eligible Person.

(n) “Exchange Act” means the Securities Exchange Act of 1934, as amended from time to time, including the guidance, rules and regulations promulgated thereunder and successor provisions, guidance, rules and regulations thereto.

(o) “Fair Market Value” of a share of Stock means, as of any specified date, (i) if the Stock is listed on a national securities exchange, the closing sales price of the Stock, as reported on the securities exchange composite tape on that date (or if no sales occur on such date, on the last preceding date on which such sales of the Stock are so reported); (ii) if the Stock is not

 

3


traded on a national securities exchange but is traded over the counter on such date, the average between the reported high and low bid and asked prices of Stock on the most recent date on which Stock was publicly traded on or preceding the specified date; or (iii) in the event Stock is not publicly traded at the time a determination of its value is required to be made under the Plan, the amount determined by the Committee in its discretion in such manner as it deems appropriate, taking into account all factors the Committee deems appropriate, including the Nonqualified Deferred Compensation Rules. Notwithstanding this definition of Fair Market Value, with respect to one or more Award types, or for any other purpose for which the Committee must determine the Fair Market Value under the Plan, the Committee may elect to choose a different measurement date or methodology for determining Fair Market Value so long as the determination is consistent with the Nonqualified Deferred Compensation Rules and all other applicable laws and regulations.

(p) Incumbent Board” means the portion of the Board constituted of the individuals who are members of the Board as of the Effective Date and any other individual who becomes a director of the Company after the Effective Date and whose election or appointment by the Board or nomination for election by the Company’s stockholders was approved by a vote of at least two-thirds of the directors then comprising the Incumbent Board, but excluding, for this purpose, any such individual whose initial assumption of office occurs as a result of an actual or threatened election contest with respect to the election or removal of directors or other actual or threatened solicitation of proxies or consents by or on behalf of a Person other than the Incumbent Board.

(q) “ISO” means an Option intended to be and designated as an “incentive stock option” within the meaning of Section 422 of the Code.

(r) “Nonqualified Deferred Compensation Rules” means the limitations or requirements of Section 409A of the Code, as amended from time to time, including the guidance and regulations promulgated thereunder and successor provisions, guidance and regulations thereto.

(s) “Nonstatutory Option” means an Option that is not an ISO.

(t) “Option” means a right, granted to an Eligible Person under Section 6(b), to purchase Stock at a specified price during specified time periods, which may either be an ISO or a Nonstatutory Option.

(u) “Other Stock-Based Award” means an Award granted to an Eligible Person under Section 6(h).

(v) “Participant” means a person who has been granted an Award under the Plan that remains outstanding, including a person who is no longer an Eligible Person.

(w) “Person” means any individual, corporation, firm, partnership, joint venture, limited liability company, estate, trust, business association, organization, governmental entity or other entity.

 

4


(x) “Qualified Member” means a member of the Board who is (i) a “non-employee director” within the meaning of Rule 16b-3(b)(3) and (ii) “independent” under the listing standards or rules of the securities exchange upon which the Stock is traded, but only to the extent such independence is required in order to take the action at issue pursuant to such standards or rules.

(y) “Restricted Stock” means Stock granted to an Eligible Person under Section 6(d) that is subject to certain restrictions and to a risk of forfeiture.

(z) “Restricted Stock Unit” means a right, granted to an Eligible Person under Section 6(e), to receive Stock, cash or a combination thereof at the end of a specified period (which may or may not be coterminous with the vesting schedule of the Award).

(aa) “Rule 16b-3” means Rule 16b-3, promulgated by the SEC under Section 16 of the Exchange Act.

(bb) “SAR” means a stock appreciation right granted to an Eligible Person under Section 6(c).

(cc) “SEC” means the Securities and Exchange Commission.

(dd) “Securities Act” means the Securities Act of 1933, as amended from time to time, including the guidance, rules and regulations promulgated thereunder and successor provisions, guidance, rules and regulations thereto.

(ee) “Stock” means the Company’s Class A common stock, par value $0.0001 per share, and such other securities as may be substituted (or re-substituted) for Stock pursuant to Section 8.

(ff) “Stock Award” means unrestricted shares of Stock granted to an Eligible Person under Section 6(f).

(gg) “Substitute Award” means an Award granted under Section 6(j).

3. Administration.

(a) Authority of the Committee. The Plan shall be administered by the Committee except to the extent the Board elects to administer the Plan, in which case references herein to the “Committee” shall be deemed to include references to the “Board.” Subject to the express provisions of the Plan, Rule 16b-3 and other applicable laws, the Committee shall have the authority, in its sole and absolute discretion, to:

(i) designate Eligible Persons as Participants;

(ii) determine the type or types of Awards to be granted to an Eligible Person;

(iii) determine the number of shares of Stock or amount of cash to be covered by Awards;

 

5


(iv) determine the terms and conditions of any Award, including whether, to what extent and under what circumstances Awards may be vested, settled, exercised, cancelled or forfeited (including conditions based on continued employment or service requirements or the achievement of one or more performance goals);

(v) modify, waive or adjust any term or condition of an Award that has been granted, which may include the acceleration of vesting, waiver of forfeiture restrictions, modification of the form of settlement of the Award (for example, from cash to Stock or vice versa), early termination of a performance period, or modification of any other condition or limitation regarding an Award;

(vi) determine the treatment of an Award upon a termination of employment or other service relationship;

(vii) impose a holding period with respect to an Award or the shares of Stock received in connection with an Award;

(viii) interpret and administer the Plan and any Award Agreement;

(ix) correct any defect, supply any omission or reconcile any inconsistency in the Plan, in any Award, or in any Award Agreement; and

(x) make any other determination and take any other action that the Committee deems necessary or desirable for the administration of the Plan.

The express grant of any specific power to the Committee, and the taking of any action by the Committee, shall not be construed as limiting any power or authority of the Committee. Any action of the Committee shall be final, conclusive and binding on all persons, including the Company, its Affiliates, stockholders, Participants, beneficiaries, and permitted transferees under Section 7(a) or other persons claiming rights from or through a Participant.

(b) Exercise of Committee Authority. At any time that a member of the Committee is not a Qualified Member, any action of the Committee relating to an Award granted or to be granted to an Eligible Person who is then subject to Section 16 of the Exchange Act in respect of the Company where such action is not taken by the full Board may be taken either (A) by a subcommittee, designated by the Committee, composed solely of two or more Qualified Members, or (B) by the Committee but with each such member who is not a Qualified Member abstaining or recusing himself or herself from such action; provided, however, that upon such abstention or recusal, the Committee remains composed solely of two or more Qualified Members. Such action, authorized by such a subcommittee or by the Committee upon the abstention or recusal of such non-Qualified Member(s), shall be the action of the Committee for purposes of the Plan. For the avoidance of doubt, the full Board may take any action relating to an Award granted or to be granted to an Eligible Person who is then subject to Section 16 of the Exchange Act in respect of the Company.

 

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(c) Delegation of Authority. The Committee may delegate any or all of its powers and duties under the Plan to a subcommittee of directors or to any officer of the Company, including the power to perform administrative functions and grant Awards; provided, however, that such delegation does not (i) violate state or corporate law or (ii) result in the loss of an exemption under Rule 16b-3(d)(1) for Awards granted to Participants subject to Section 16 of the Exchange Act in respect of the Company. Upon any such delegation, all references in the Plan to the “Committee,” other than in Section 5(b) or Section 8, shall be deemed to include any subcommittee or officer of the Company to whom such powers have been delegated by the Committee. Any such delegation shall not limit the right of such subcommittee members or such an officer to receive Awards; provided, however, that such subcommittee members and any such officer may not grant Awards to himself or herself, a member of the Board, or any executive officer of the Company or an Affiliate, or take any action with respect to any Award previously granted to himself or herself, a member of the Board, or any executive officer of the Company or an Affiliate. The Committee may also appoint agents who are not executive officers of the Company or members of the Board to assist in administering the Plan, provided that such individuals may not be delegated the authority to grant or modify any Awards that will, or may, be settled in Stock.

(d) Limitation of Liability. The Committee and each member thereof shall be entitled to, in good faith, rely or act upon any report or other information furnished to him or her by any officer or employee of the Company or any of its Affiliates, the Company’s legal counsel, independent auditors, consultants or any other agents assisting in the administration of the Plan. Members of the Committee and any officer or employee of the Company or any of its Affiliates acting at the direction or on behalf of the Committee shall not be personally liable for any action or determination taken or made in good faith with respect to the Plan, and shall, to the fullest extent permitted by law, be indemnified and held harmless by the Company with respect to any such action or determination.

(e) Participants in Non-U.S. Jurisdictions. Notwithstanding any provision of the Plan to the contrary, to comply with applicable laws in countries other than the United States in which the Company or any of its Affiliates operates or has employees, directors or other service providers from time to time, or to ensure that the Company complies with any applicable requirements of foreign securities exchanges, the Committee, in its sole discretion, shall have the power and authority to: (i) determine which of the Company’s Affiliates shall be covered by the Plan; (ii) determine which Eligible Persons outside the United States are eligible to participate in the Plan; (iii) modify the terms and conditions of any Award granted to Eligible Persons outside the United States to comply with applicable foreign laws or listing requirements of any foreign exchange; (iv) establish sub-plans and modify exercise procedures and other terms and procedures, to the extent such actions may be necessary or advisable (any such sub-plans and/or modifications shall be attached to the Plan as appendices), provided, however, that no such sub-plans and/or modifications shall increase the share limitations contained in Section 4(a); and (v) take any action, before or after an Award is granted, that it deems advisable to comply with any applicable governmental regulatory exemptions or approval or listing requirements of any such foreign securities exchange. For purposes of the Plan, all references to foreign laws, rules, regulations or taxes shall be references to the laws, rules, regulations and taxes of any applicable jurisdiction other than the United States or a political subdivision thereof.

 

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4. Stock Subject to Plan.

(a) Number of Shares Available for Delivery. Subject to adjustment in a manner consistent with Section 8, the total number of shares of Stock reserved and available for delivery with respect to Awards under the Plan is equal to 8,384,083 shares of Stock, and such number of shares of Stock shall be available for the issuance of shares upon the exercise of ISOs.

(b) Application of Limitation to Grants of Awards. Subject to Section 4(c), no Award may be granted if the number of shares of Stock that may be delivered in connection with such Award exceeds the number of shares of Stock remaining available under the Plan minus the number of shares of Stock issuable in settlement of or relating to then-outstanding Awards. The Committee may adopt reasonable counting procedures to ensure appropriate counting, avoid double counting (as, for example, in the case of tandem or Substitute Awards) and make adjustments if the number of shares of Stock actually delivered differs from the number of shares previously counted in connection with an Award.

(c) Availability of Shares Not Delivered under Awards. If all or any portion of an Award expires or is cancelled, forfeited, exchanged, settled in cash or otherwise terminated, the shares of Stock subject to such Award (including (i) shares forfeited with respect to Restricted Stock, (ii) the number of shares withheld or surrendered to the Company in payment of any exercise or purchase price of an Award or taxes relating to Awards, and (iii) shares that were subject to an Option or SAR but were not issued or delivered as a result of net settlement or net exercise of such Option or SAR) shall not be considered “delivered shares” under the Plan, shall be available for delivery with respect to Awards, and shall no longer be considered issuable or related to outstanding Awards for purposes of Section 4(b). If an Award may be settled only in cash, such Award need not be counted against any share limit under this Section 4.

(d) Stock Offered. The shares of Stock to be delivered under the Plan shall be made available from (i) authorized but unissued shares of Stock, (ii) Stock held in the treasury of the Company, or (iii) previously issued shares of Stock reacquired by the Company, including shares purchased on the open market.

5. Eligibility; Director Award Limitations.

(a) Awards may be granted under the Plan only to Eligible Persons.

(b) In each calendar year during any part of which the Plan is in effect, a non-employee member of the Board may not be granted Awards having a value (determined, if applicable, pursuant to ASC Topic 718) on the date of grant in excess of $750,000; provided, that, for the calendar year in which a non-employee member of the Board first commences service on the Board only, the foregoing limitation shall be $1,000,000; provided, further that, the limitation set forth in this Section 5(b) shall be without regard to grants of Awards, if any, made to a non-employee member of the Board during any period in which such individual was an employee of the Company or of any of its Affiliates or was otherwise providing services to the Company or to any of its Affiliates other than in the capacity as a director of the Company.

 

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6. Specific Terms of Awards.

(a) General. Awards may be granted on the terms and conditions set forth in this Section 6. Awards granted under the Plan may, in the discretion of the Committee, be granted either alone, in addition to, or in tandem with any other Award. In addition, the Committee may impose on any Award or the exercise thereof, at the date of grant or thereafter (subject to Section 10), such additional terms and conditions, not inconsistent with the provisions of the Plan, as the Committee shall determine. Without limiting the scope of the preceding sentence, the Committee may use such business criteria and other measures of performance as it may deem appropriate in establishing any performance goals applicable to an Award, and any such performance goals may differ among Awards granted to any one Participant or to different Participants. To the extent provided in an Award Agreement, the Committee may exercise its discretion to reduce or increase the amounts payable under any Award.

(b) Options. The Committee is authorized to grant Options, which may be designated as either ISOs or Nonstatutory Options, to Eligible Persons on the following terms and conditions:

(i) Exercise Price. Each Award Agreement evidencing an Option shall state the exercise price per share of Stock (the “Exercise Price”) established by the Committee; provided, however, that except as provided in Section 6(j) or in Section 8, the Exercise Price of an Option shall not be less than the greater of (A) the par value per share of the Stock or (B) 100% of the Fair Market Value per share of the Stock as of the date of grant of the Option (or in the case of an ISO granted to an individual who owns stock possessing more than 10% of the total combined voting power of all classes of stock of the Company or its parent or any of its subsidiaries, 110% of the Fair Market Value per share of the Stock on the date of grant). Notwithstanding the foregoing, the Exercise Price of a Nonstatutory Option may be less than 100% of the Fair Market Value per share of Stock as of the date of grant of the Option if the Option (1) does not provide for a deferral of compensation by reason of satisfying the short-term deferral exception set forth in the Nonqualified Deferred Compensation Rules or (2) provides for a deferral of compensation and is compliant with the Nonqualified Deferred Compensation Rules.

(ii) Time and Method of Exercise; Other Terms. The Committee shall determine the methods by which the Exercise Price may be paid or deemed to be paid, the form of such payment, including cash or cash equivalents, Stock (including previously owned shares or through a cashless exercise, i.e., “net settlement”, a broker-assisted exercise, or other reduction of the amount of shares otherwise issuable pursuant to the Option), other Awards or awards granted under other plans of the Company or any Affiliate, other property, or any other legal consideration the Committee deems appropriate (including notes or other contractual obligations of Participants to make payment on a deferred basis), the methods by or forms in which Stock will be delivered or deemed to be delivered to Participants, including the delivery of Restricted Stock subject to Section 6(d), and any other terms and conditions of any Option. In the case of an exercise whereby the Exercise Price is paid with Stock, such Stock shall be valued based on the Stock’s Fair Market Value as of the date of exercise. No Option may be exercisable for a period of more than ten years following the date of grant of the Option (or in the case of an ISO granted to an individual who owns stock possessing more than 10% of the total combined voting power of all classes of stock of the Company or its parent or any of its subsidiaries, for a period of more than five years following the date of grant of the ISO).

 

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(iii) ISOs. The terms of any ISO granted under the Plan shall comply in all respects with the provisions of Section 422 of the Code. ISOs may only be granted to Eligible Persons who are employees of the Company or employees of a parent or any subsidiary corporation of the Company. Except as otherwise provided in Section 8, no term of the Plan relating to ISOs (including any SAR in tandem therewith) shall be interpreted, amended or altered, nor shall any discretion or authority granted under the Plan be exercised, so as to disqualify either the Plan or any ISO under Section 422 of the Code, unless the Participant has first requested the change that will result in such disqualification. ISOs shall not be granted more than ten years after the earlier of the adoption of the Plan or the approval of the Plan by the Company’s stockholders. Notwithstanding the foregoing, to the extent that the aggregate Fair Market Value of shares of Stock subject to an ISO and the aggregate Fair Market Value of shares of stock of any parent or subsidiary corporation (within the meaning of Sections 424(e) and (f) of the Code) subject to any other incentive stock options of the Company or a parent or subsidiary corporation (within the meaning of Sections 424(e) and (f) of the Code) that are exercisable for the first time by a Participant during any calendar year exceeds $100,000, or such other amount as may be prescribed under Section 422 of the Code, such excess shall be treated as Nonstatutory Options in accordance with the Code. As used in the previous sentence, Fair Market Value shall be determined as of the date the ISO is granted. If a Participant shall make any disposition of shares of Stock issued pursuant to an ISO under the circumstances described in Section 421(b) of the Code (relating to disqualifying dispositions), the Participant shall notify the Company of such disposition within the time provided to do so in the applicable award agreement.

(c) SARs. The Committee is authorized to grant SARs to Eligible Persons on the following terms and conditions:

(i) Right to Payment. An SAR is a right to receive, upon exercise thereof, an amount equal to the product of (i) the excess of (A) the Fair Market Value of one share of Stock on the date of exercise over (B) the grant price of the SAR as determined by the Committee and (ii) the number of shares of Stock subject to the exercise of the SAR.

(ii) Grant Price. Each Award Agreement evidencing an SAR shall state the grant price per share of Stock established by the Committee; provided, however, that except as provided in Section 6(j) or in Section 8, the grant price per share of Stock subject to an SAR shall not be less than the greater of (A) the par value per share of the Stock or (B) 100% of the Fair Market Value per share of the Stock as of the date of grant of the SAR. Notwithstanding the foregoing, the grant price of an SAR may be less than 100% of the Fair Market Value per share of Stock subject to an SAR as of the date of grant of the SAR if the SAR (1) does not provide for a deferral of compensation by reason of satisfying the short-term deferral exception set forth in the Nonqualified Deferred Compensation Rules or (2) provides for a deferral of compensation and is compliant with the Nonqualified Deferred Compensation Rules.

(iii) Method of Exercise and Settlement; Other Terms. The Committee shall determine the form of consideration payable upon settlement, the method by or forms in which Stock (if any), cash or a combination thereof, as determined by the Committee in its sole discretion, will be delivered or deemed to be delivered to Participants, and any other terms and conditions of any SAR. SARs may be either free-standing or granted in tandem with other Awards. No SAR may be exercisable for a period of more than ten years following the date of grant of the SAR.

 

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(iv) Rights Related to Options. An SAR granted in connection with an Option shall entitle a Participant, upon exercise, to surrender that Option or any portion thereof, to the extent unexercised, and to receive payment of an amount determined by multiplying (A) the difference obtained by subtracting the Exercise Price with respect to a share of Stock specified in the related Option from the Fair Market Value of a share of Stock on the date of exercise of the SAR, by (B) the number of shares as to which that SAR has been exercised. The Option shall then cease to be exercisable to the extent surrendered. SARs granted in connection with an Option shall be subject to the terms and conditions of the Award Agreement governing the Option, which shall provide that the SAR is exercisable only at such time or times and only to the extent that the related Option is exercisable and shall not be transferable except to the extent that the related Option is transferrable.

(d) Restricted Stock. The Committee is authorized to grant Restricted Stock to Eligible Persons on the following terms and conditions:

(i) Restrictions. Restricted Stock shall be subject to such restrictions on transferability, risk of forfeiture and other restrictions, if any, as the Committee may impose. Except as provided in Section 7(a)(iii) and Section 7(a)(iv), during the restricted period applicable to the Restricted Stock, the Restricted Stock may not be sold, transferred, pledged, hedged, hypothecated, margined or otherwise encumbered by the Participant.

(ii) Dividends and Splits. As a condition to the grant of an Award of Restricted Stock, the Committee may provide that any cash dividends paid on a share of Restricted Stock be (1) paid or distributed when accrued or at a later specified date, (2) automatically reinvested in additional shares of Restricted Stock, (3) applied to the purchase of additional Awards, (4) deferred without interest to the date of vesting of the associated Award of Restricted Stock or (5) subject to such other terms and conditions as the Committee may specify. Unless otherwise determined by the Committee and specified in the applicable Award Agreement, Stock distributed in connection with a Stock split or Stock dividend, and other property (other than cash) distributed as a dividend, shall be subject to restrictions and a risk of forfeiture to the same extent as the Restricted Stock with respect to which such Stock or other property has been distributed.

(e) Restricted Stock Units. The Committee is authorized to grant Restricted Stock Units to Eligible Persons on the following terms and conditions:

(i) Award and Restrictions. Restricted Stock Units shall be subject to such restrictions (which may include a risk of forfeiture) as the Committee may impose.

(ii) Settlement. Settlement of vested Restricted Stock Units shall occur upon vesting or upon expiration of the deferral period specified for such Restricted Stock Units by the Committee (or, if permitted by the Committee, as elected by the Participant). Restricted Stock Units shall be settled by delivery of (A) a number of shares of Stock equal to the number of Restricted Stock Units for which settlement is due, or (B) cash in an amount equal to the Fair Market Value of the specified number of shares of Stock equal to the number of Restricted Stock Units for which settlement is due, or a combination thereof, as determined by the Committee at the date of grant or thereafter.

 

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(f) Stock Awards. The Committee is authorized to grant Stock Awards to Eligible Persons as a bonus, as additional compensation, or in lieu of cash compensation any such Eligible Person is otherwise entitled to receive, in such amounts and subject to such other terms as the Committee in its discretion determines to be appropriate.

(g) Dividend Equivalents. The Committee is authorized to grant Dividend Equivalents to Eligible Persons, entitling any such Eligible Person to receive cash, Stock, other Awards, or other property equal in value to dividends or other distributions paid with respect to a specified number of shares of Stock. Dividend Equivalents may be awarded on a free-standing basis or in connection with another Award (other than an Award of Restricted Stock or a Stock Award). The Committee may provide that Dividend Equivalents shall be paid or distributed when accrued or at a later specified date and, if distributed at a later date, may be deemed to have been reinvested in additional Stock, Awards, or other investment vehicles or accrued in a bookkeeping account without interest, and subject to such restrictions on transferability and risks of forfeiture, as the Committee may specify. With respect to Dividend Equivalents granted in connection with another Award, absent a contrary provision in the Award Agreement, such Dividend Equivalents shall be subject to the same restrictions and risk of forfeiture as the Award with respect to which the dividends accrue and shall not be paid unless and until such Award has vested and been earned.

(h) Other Stock-Based Awards. The Committee is authorized, subject to limitations under applicable law, to grant to Eligible Persons such other Awards that may be denominated or payable in, valued in whole or in part by reference to, or otherwise based on, or related to, Stock, as deemed by the Committee to be consistent with the purposes of the Plan, including convertible or exchangeable debt securities, other rights convertible or exchangeable into Stock, purchase rights for Stock, Awards with value and payment contingent upon performance of the Company or any other factors designated by the Committee, and Awards valued by reference to the book value of Stock or the value of securities of, or the performance of, specified Affiliates of the Company. The Committee shall determine the terms and conditions of such Other Stock-Based Awards. Stock delivered pursuant to an Other-Stock Based Award in the nature of a purchase right granted under this Section 6(h) shall be purchased for such consideration, paid for at such times, by such methods, and in such forms, including cash, Stock, other Awards, or other property, as the Committee shall determine.

(i) Cash Awards. The Committee is authorized to grant Cash Awards, on a free-standing basis or as an element of, a supplement to, or in lieu of any other Award under the Plan to Eligible Persons in such amounts and subject to such other terms as the Committee in its discretion determines to be appropriate.

(j) Substitute Awards; No Repricing. Awards may be granted in substitution or exchange for any other Award granted under the Plan or under another plan of the Company or an Affiliate or any other right of an Eligible Person to receive payment from the Company or an Affiliate. Awards may also be granted under the Plan in substitution for awards held by individuals who become Eligible Persons as a result of a merger, consolidation or acquisition of another entity or the assets of another entity by or with the Company or an Affiliate. Such Substitute Awards

 

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referred to in the immediately preceding sentence that are Options or SARs may have an exercise price that is less than the Fair Market Value of a share of Stock on the date of the substitution if such substitution complies with the Nonqualified Deferred Compensation Rules and other applicable laws and exchange rules. Except as provided in this Section 6(j) or in Section 8, without the approval of the stockholders of the Company, the terms of outstanding Awards may not be amended to (i) reduce the Exercise Price or grant price of an outstanding Option or SAR, (ii) grant a new Option, SAR or other Award in substitution for, or upon the cancellation of, any previously granted Option or SAR that has the effect of reducing the Exercise Price or grant price thereof, (iii) exchange any Option or SAR for Stock, cash or other consideration when the Exercise Price or grant price per share of Stock under such Option or SAR exceeds the Fair Market Value of a share of Stock or (iv) take any other action that would be considered a “repricing” of an Option or SAR under the applicable listing standards of the national securities exchange on which the Stock is listed (if any).

7. Certain Provisions Applicable to Awards.

(a) Limit on Transfer of Awards.

(i) Except as provided in Sections 7(a)(iii) and (iv), each Option and SAR shall be exercisable only by the Participant during the Participant’s lifetime, or by the person to whom the Participant’s rights shall pass by will or the laws of descent and distribution. Notwithstanding anything to the contrary in this Section 7(a), an ISO shall not be transferable other than by will or the laws of descent and distribution.

(ii) Except as provided in Sections 7(a)(i), (iii) and (iv), no Award, other than a Stock Award, and no right under any such Award, may be assigned, alienated, pledged, attached, sold or otherwise transferred or encumbered by a Participant and any such purported assignment, alienation, pledge, attachment, sale, transfer or encumbrance shall be void and unenforceable against the Company or any Affiliate.

(iii) To the extent specifically provided by the Committee, an Award may be transferred by a Participant without consideration to immediate family members or related family trusts, limited partnerships or similar entities or on such terms and conditions as the Committee may from time to time establish.

(iv) An Award may be transferred pursuant to a domestic relations order entered or approved by a court of competent jurisdiction upon delivery to the Company of a written request for such transfer and a certified copy of such order.

(b) Form and Timing of Payment under Awards; Deferrals. Subject to the terms of the Plan and any applicable Award Agreement, payments to be made by the Company or any of its Affiliates upon the exercise or settlement of an Award may be made in such forms as the Committee shall determine in its discretion, including cash, Stock, other Awards or other property, and may be made in a single payment or transfer, in installments, or on a deferred basis (which may be required by the Committee or permitted at the election of the Participant on terms and conditions established by the Committee); provided, however, that any such deferred or installment payments will be set forth in the Award Agreement. Payments may include, without limitation, provisions for the payment or crediting of reasonable interest on installment or deferred payments or the grant or crediting of Dividend Equivalents or other amounts in respect of installment or deferred payments denominated in Stock.

 

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(c) Evidencing Stock. The Stock or other securities of the Company delivered pursuant to an Award may be evidenced in any manner deemed appropriate by the Committee in its sole discretion, including in the form of a certificate issued in the name of the Participant or by book entry, electronic or otherwise, and shall be subject to such stop transfer orders and other restrictions as the Committee may deem advisable under the Plan or the rules, regulations, and other requirements of the SEC, any securities exchange upon which such Stock or other securities are then listed, and any applicable federal, state or other laws, and the Committee may cause a legend or legends to be inscribed on any such certificates to make appropriate reference to such restrictions. Further, if certificates representing Restricted Stock are registered in the name of the Participant, the Company may retain physical possession of the certificates and may require that the Participant deliver a stock power to the Company, endorsed in blank, related to the Restricted Stock.

(d) Consideration for Grants. Awards may be granted for such consideration, including services, as the Committee shall determine, but shall not be granted for less than the minimum lawful consideration.

(e) Additional Agreements. Each Eligible Person to whom an Award is granted under the Plan may be required to agree in writing, as a condition to the grant of such Award or otherwise, to subject an Award that is exercised or settled following such Eligible Person’s termination of employment or service to a general release of claims and/or a noncompetition or other restricted covenant agreement in favor of the Company and its Affiliates, with the terms and conditions of such agreement(s) to be determined in good faith by the Committee.

8. Subdivision or Consolidation; Recapitalization; Change in Control; Reorganization.

(a) Existence of Plans and Awards. The existence of the Plan and the Awards granted hereunder shall not affect in any way the right or power of the Company, the Board or the stockholders of the Company to make or authorize any adjustment, recapitalization, reorganization or other change in the Company’s capital structure or its business, any merger or consolidation of the Company, any issue of debt or equity securities ahead of or affecting Stock or the rights thereof, the dissolution or liquidation of the Company or any sale, lease, exchange or other disposition of all or any part of its assets or business or any other corporate act or proceeding.

(b) Additional Issuances. Except as expressly provided herein, the issuance by the Company of shares of stock of any class, including upon conversion of shares or obligations of the Company convertible into such shares or other securities, and in any case whether or not for fair value, shall not affect, and no adjustment by reason thereof shall be made with respect to, the number of shares of Stock subject to Awards theretofore granted or the purchase price per share of Stock, if applicable.

 

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(c) Subdivision or Consolidation of Shares. The terms of an Award and the share limitations under the Plan shall be subject to adjustment by the Committee from time to time, in accordance with the following provisions:

(i) If at any time, or from time to time, the Company shall subdivide as a whole (by reclassification, by a Stock split, by the issuance of a distribution on Stock payable in Stock, or otherwise) the number of shares of Stock then outstanding into a greater number of shares of Stock or in the event the Company distributes an extraordinary cash dividend, then, as appropriate (A) the maximum number of shares of Stock available for delivery with respect to Awards and applicable limitations with respect to Awards provided in Section 4 and Section 5 (other than cash limits) shall be increased proportionately, and the kind of shares or other securities available for the Plan shall be appropriately adjusted, (B) the number of shares of Stock (or other kind of shares or securities) that may be acquired under any then outstanding Award shall be increased proportionately, and (C) the price (including the Exercise Price or grant price) for each share of Stock (or other kind of shares or securities) subject to then outstanding Awards shall be reduced proportionately, without changing the aggregate purchase price or value as to which outstanding Awards remain exercisable or subject to restrictions; provided, however, that in the case of an extraordinary cash dividend that is not an Adjustment Event, the adjustment to the number of shares of Stock and the Exercise Price or grant price, as applicable, with respect to an outstanding Option or SAR may be made in such other manner as the Committee may determine that is permitted pursuant to applicable tax and other laws, rules and regulations.

(ii) If at any time, or from time to time, the Company shall consolidate as a whole (by reclassification, by reverse Stock split, or otherwise) the number of shares of Stock then outstanding into a lesser number of shares of Stock, then, as appropriate (A) the maximum number of shares of Stock available for delivery with respect to Awards and applicable limitations with respect to Awards provided in Section 4 and Section 5 (other than cash limits) shall be decreased proportionately, and the kind of shares or other securities available for the Plan shall be appropriately adjusted, (B) the number of shares of Stock (or other kind of shares or securities) that may be acquired under any then outstanding Award shall be decreased proportionately, and (C) the price (including the Exercise Price or grant price) for each share of Stock (or other kind of shares or securities) subject to then outstanding Awards shall be increased proportionately, without changing the aggregate purchase price or value as to which outstanding Awards remain exercisable or subject to restrictions.

(d) Recapitalization. In the event of any change in the capital structure or business of the Company or other corporate transaction or event that would be considered an “equity restructuring” within the meaning of ASC Topic 718 and, in each case, that would result in an additional compensation expense to the Company pursuant to the provisions of ASC Topic 718, if adjustments to Awards with respect to such event were discretionary or otherwise not required (each such an event, an “Adjustment Event”), then the Committee shall equitably adjust (i) the aggregate number or kind of shares that thereafter may be delivered under the Plan, (ii) the number or kind of shares or other property (including cash) subject to an Award, (iii) the terms and conditions of Awards, including the purchase price or Exercise Price of Awards and performance goals, as applicable, and (iv) the applicable limitations with respect to Awards provided in Section 4 and Section 5 (other than cash limits) to equitably reflect such Adjustment Event (“Equitable Adjustments”). In the event of any change in the capital structure or business

 

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of the Company or other corporate transaction or event that would not be considered an Adjustment Event, and is not otherwise addressed in this Section 8, the Committee shall have complete discretion to make Equitable Adjustments (if any) in such manner as it deems appropriate with respect to such other event.

(e) Change in Control and Other Events. Except to the extent otherwise provided in any applicable Award Agreement, vesting of any Award shall not occur solely upon the occurrence of a Change in Control and, in the event of a Change in Control or other changes in the Company or the outstanding Stock by reason of a recapitalization, reorganization, merger, consolidation, combination, exchange or other relevant change occurring after the date of the grant of any Award, the Committee, acting in its sole discretion without the consent or approval of any holder, may exercise any power enumerated in Section 3 (including the power to accelerate vesting, waive any forfeiture conditions or otherwise modify or adjust any other condition or limitation regarding an Award) and may also effect one or more of the following alternatives, which may vary among individual holders and which may vary among Awards held by any individual holder:

(i) accelerate the time of exercisability of an Award so that such Award may be exercised in full or in part for a limited period of time on or before a date specified by the Committee, after which specified date all unexercised Awards and all rights of holders thereunder shall terminate;

(ii) redeem in whole or in part outstanding Awards by requiring the mandatory surrender to the Company by selected holders of some or all of the outstanding Awards held by such holders (irrespective of whether such Awards are then vested or exercisable) as of a date, specified by the Committee, in which event the Committee shall thereupon cancel such Awards and pay to each holder an amount of cash or other consideration per Award (other than a Dividend Equivalent or Cash Award, which the Committee may separately require to be surrendered in exchange for cash or other consideration determined by the Committee in its discretion) equal to the Change in Control Price, less the Exercise Price with respect to an Option and less the grant price with respect to a SAR, as applicable to such Awards; provided, however, that to the extent the Exercise Price of an Option or the grant price of an SAR exceeds the Change in Control Price, such Award may be cancelled for no consideration;

(iii) cancel Awards that remain subject to a restricted period as of the date of a Change in Control or other such event without payment of any consideration to the Participant for such Awards; or

(iv) make such adjustments to Awards then outstanding as the Committee deems appropriate to reflect such Change in Control or other such event (including the substitution, assumption, or continuation of Awards by the successor company or a parent or subsidiary thereof);

provided, however, that so long as the event is not an Adjustment Event, the Committee may determine in its sole discretion that no adjustment is necessary to Awards then outstanding. If an Adjustment Event occurs, this Section 8(e) shall only apply to the extent it is not in conflict with Section 8(d).

 

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9. General Provisions.

(a) Tax Withholding. The Company and any of its Affiliates are authorized to withhold from any Award granted, or any payment relating to an Award, including from a distribution of Stock, taxes due or potentially payable in connection with any transaction involving an Award, and to take such other action as the Committee may deem advisable to enable the Company, its Affiliates and Participants to satisfy the payment of withholding taxes and other tax obligations relating to any Award in such amounts as may be determined by the Committee. The Committee shall determine, in its sole discretion, the form of payment acceptable for such tax withholding obligations, including the delivery of cash or cash equivalents, Stock (including previously owned shares, net settlement, a broker-assisted sale, or other cashless withholding or reduction of the amount of shares otherwise issuable or delivered pursuant to the Award), other property, or any other legal consideration the Committee deems appropriate. Any determination made by the Committee to allow a Participant who is subject to Rule 16b-3 to pay taxes with shares of Stock through net settlement or previously owned shares shall be approved by either a committee made up of solely two or more Qualified Members or the full Board. If such tax withholding amounts are satisfied through net settlement or previously owned shares, the maximum number of shares of Stock that may be so withheld or surrendered shall be the number of shares of Stock that have an aggregate Fair Market Value on the date of withholding or surrender equal to the aggregate amount of such tax liabilities determined based on the greatest withholding rates for federal, state, foreign and/or local tax purposes, including payroll taxes, that may be utilized without creating adverse accounting treatment for the Company with respect to such Award, as determined by the Committee.

(b) Limitation on Rights Conferred under Plan. Neither the Plan nor any action taken hereunder shall be construed as (i) giving any Eligible Person or Participant the right to continue as an Eligible Person or Participant or in the employ or service of the Company or any of its Affiliates, (ii) interfering in any way with the right of the Company or any of its Affiliates to terminate any Eligible Person’s or Participant’s employment or service relationship at any time, (iii) giving an Eligible Person or Participant any claim to be granted any Award under the Plan or to be treated uniformly with other Participants and/or employees and/or other service providers, or (iv) conferring on a Participant any of the rights of a stockholder of the Company unless and until the Participant is duly issued or transferred shares of Stock in accordance with the terms of an Award.

(c) Governing Law; Submission to Jurisdiction. All questions arising with respect to the provisions of the Plan and Awards shall be determined by application of the laws of the State of Delaware, without giving effect to any conflict of law provisions thereof, except to the extent Delaware law is preempted by federal law. The obligation of the Company to sell and deliver Stock hereunder is subject to applicable federal and state laws and to the approval of any governmental authority required in connection with the authorization, issuance, sale, or delivery of such Stock. With respect to any claim or dispute related to or arising under the Plan, the Company and each Participant who accepts an Award hereby consent to the exclusive jurisdiction, forum and venue of the state and federal courts located in Denver, Colorado.

 

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(d) Severability and Reformation. If any provision of the Plan or any Award is or becomes or is deemed to be invalid, illegal, or unenforceable in any jurisdiction or as to any person or Award, or would disqualify the Plan or any Award under any law deemed applicable by the Committee, such provision shall be construed or deemed amended to conform to the applicable law or, if it cannot be construed or deemed amended without, in the determination of the Committee, materially altering the intent of the Plan or the Award, such provision shall be stricken as to such jurisdiction, person or Award and the remainder of the Plan and any such Award shall remain in full force and effect. If any of the terms or provisions of the Plan or any Award Agreement conflict with the requirements of Rule 16b-3 (as those terms or provisions are applied to Eligible Persons who are subject to Section 16 of the Exchange Act), or Section 422 of the Code (with respect to ISOs), then those conflicting terms or provisions shall be deemed inoperative to the extent they so conflict with the requirements of Rule 16b-3 (unless the Board or the Committee, as appropriate, has expressly determined that the Plan or such Award should not comply with Rule 16b-3) or Section 422 of the Code, in each case, only to the extent Rule 16b-3 and such sections of the Code are applicable. With respect to ISOs, if the Plan does not contain any provision required to be included herein under Section 422 of the Code, that provision shall be deemed to be incorporated herein with the same force and effect as if that provision had been set out at length herein; provided, further, that, to the extent any Option that is intended to qualify as an ISO cannot so qualify, that Option (to that extent) shall be deemed a Nonstatutory Option for all purposes of the Plan.

(e) Unfunded Status of Awards; No Trust or Fund Created. The Plan is intended to constitute an “unfunded” plan for certain incentive awards. Neither the Plan nor any Award shall create or be construed to create a trust or separate fund of any kind or a fiduciary relationship between the Company or any Affiliate and a Participant or any other person. To the extent that any person acquires a right to receive payments from the Company or any Affiliate pursuant to an Award, such right shall be no greater than the right of any general unsecured creditor of the Company or such Affiliate.

(f) Nonexclusivity of the Plan. Neither the adoption of the Plan by the Board nor its submission to the stockholders of the Company for approval shall be construed as creating any limitations on the power of the Board or a committee thereof to adopt such other incentive arrangements as it may deem desirable. Nothing contained in the Plan shall be construed to prevent the Company or any of its Affiliates from taking any corporate action which is deemed by the Company or such Affiliate to be appropriate or in its best interest, whether or not such action would have an adverse effect on the Plan or any Award made under the Plan. No employee, beneficiary or other person shall have any claim against the Company or any of its Affiliates as a result of any such action.

(g) Fractional Shares. No fractional shares of Stock shall be issued or delivered pursuant to the Plan or any Award, and the Committee shall determine in its sole discretion whether cash, other securities, or other property shall be paid or transferred in lieu of any fractional shares of Stock or whether such fractional shares of Stock or any rights thereto shall be cancelled, terminated, or otherwise eliminated with or without consideration.

 

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(h) Interpretation. Headings are given to the Sections and subsections of the Plan solely as a convenience to facilitate reference. Such headings shall not be deemed in any way material or relevant to the construction or interpretation of the Plan or any provision thereof. Words in the masculine gender shall include the feminine gender, and, where appropriate, the plural shall include the singular and the singular shall include the plural. In the event of any conflict between the terms and conditions of an Award Agreement and the Plan, the provisions of the Plan shall control. The use herein of the word “including” following any general statement, term or matter shall not be construed to limit such statement, term or matter to the specific items or matters set forth immediately following such word or to similar items or matters, whether or not non-limiting language (such as “without limitation”, “but not limited to”, or words of similar import) is used with reference thereto, but rather shall be deemed to refer to all other items or matters that could reasonably fall within the broadest possible scope of such general statement, term or matter. References herein to any agreement, instrument or other document means such agreement, instrument or other document as amended, supplemented and modified from time to time to the extent permitted by the provisions thereof and not prohibited by the Plan.

(i) Facility of Payment. Any amounts payable hereunder to any individual under legal disability or who, in the judgment of the Committee, is unable to manage properly his financial affairs, may be paid to the legal representative of such individual, or may be applied for the benefit of such individual in any manner that the Committee may select, and the Company shall be relieved of any further liability for payment of such amounts.

(j) Conditions to Delivery of Stock. Nothing herein or in any Award Agreement shall require the Company to issue any shares with respect to any Award if that issuance would, in the opinion of counsel for the Company, constitute a violation of the Securities Act, any other applicable statute or regulation, or the rules of any applicable securities exchange or securities association, as then in effect. In addition, each Participant who receives an Award under the Plan shall not sell or otherwise dispose of Stock that is acquired upon grant, exercise or vesting of an Award in any manner that would constitute a violation of any applicable federal or state securities laws, the Plan or the rules, regulations or other requirements of the SEC or any securities exchange upon which the Stock is then listed. At the time of any exercise of an Option or SAR, or at the time of any grant of any other Award, the Company may, as a condition precedent to the exercise of such Option or SAR or settlement of any other Award, require from the Participant (or in the event of his or her death, his or her legal representatives, heirs, legatees, or distributees) such written representations, if any, concerning the holder’s intentions with regard to the retention or disposition of the shares of Stock being acquired pursuant to the Award and such written covenants and agreements, if any, as to the manner of disposal of such shares as, in the opinion of counsel to the Company, may be necessary to ensure that any disposition by that holder (or in the event of the holder’s death, his or her legal representatives, heirs, legatees, or distributees) will not involve a violation of the Securities Act, any other applicable state or federal statute or regulation, or any rule of any applicable securities exchange or securities association, as then in effect. Stock or other securities shall not be delivered pursuant to any Award until payment in full of any amount required to be paid pursuant to the Plan or the applicable Award Agreement (including any Exercise Price, grant price, or tax withholding) is received by the Company.

(k) Section 409A of the Code. It is the general intention, but not the obligation, of the Committee to design Awards to comply with or to be exempt from the Nonqualified Deferred Compensation Rules, and Awards will be operated and construed accordingly. Neither this Section 9(k) nor any other provision of the Plan is or contains a representation to any

 

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Participant regarding the tax consequences of the grant, vesting, exercise, settlement, or sale of any Award (or the Stock underlying such Award) granted hereunder, and should not be interpreted as such. In no event shall the Company be liable for all or any portion of any taxes, penalties, interest or other expenses that may be incurred by the Participant on account of non-compliance with the Nonqualified Deferred Compensation Rules. Notwithstanding any provision in the Plan or an Award Agreement to the contrary, in the event that a “specified employee” (as defined under the Nonqualified Deferred Compensation Rules) becomes entitled to a payment under an Award that would be subject to additional taxes and interest under the Nonqualified Deferred Compensation Rules if the Participant’s receipt of such payment or benefits is not delayed until the earlier of (i) the date of the Participant’s death, or (ii) the date that is six months after the Participant’s “separation from service,” as defined under the Nonqualified Deferred Compensation Rules (such date, the “Section 409A Payment Date”), then such payment or benefit shall not be provided to the Participant until the Section 409A Payment Date. Any amounts subject to the preceding sentence that would otherwise be payable prior to the Section 409A Payment Date will be aggregated and paid in a lump sum without interest on the Section 409A Payment Date. The applicable provisions of the Nonqualified Deferred Compensation Rules are hereby incorporated by reference and shall control over any Plan or Award Agreement provision in conflict therewith.

(l) Clawback. The Plan and all Awards granted hereunder are subject to any written clawback policies that the Company, with the approval of the Board or an authorized committee thereof, may adopt either prior to or following the Effective Date, including any policy adopted to conform to the Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010 and rules promulgated thereunder by the SEC and that the Company determines should apply to Awards. Any such policy may subject a Participant’s Awards and amounts paid or realized with respect to Awards to reduction, cancelation, forfeiture or recoupment if certain specified events or wrongful conduct occur, including an accounting restatement due to the Company’s material noncompliance with financial reporting regulations or other events or wrongful conduct specified in any such clawback policy.

(m) Status under ERISA. The Plan shall not constitute an “employee benefit plan” for purposes of Section 3(3) of the Employee Retirement Income Security Act of 1974, as amended.

(n) Plan Effective Date and Term. The Plan was adopted by the Board to be effective on the Effective Date. No Awards may be granted under the Plan on and after the tenth anniversary of the Effective Date. However, any Award granted prior to such termination (or any earlier termination pursuant to Section 10), and the authority of the Board or Committee to amend, alter, adjust, suspend, discontinue, or terminate any such Award or to waive any conditions or rights under such Award in accordance with the terms of the Plan, shall extend beyond such termination until the final disposition of such Award.

10. Amendments to the Plan and Awards. The Committee may amend, alter, suspend, discontinue or terminate any Award or Award Agreement, the Plan or the Committee’s authority to grant Awards without the consent of stockholders or Participants, except that any amendment or alteration to the Plan, including any increase in any share limitation, shall be subject to the approval of the Company’s stockholders not later than the annual meeting next following such Committee action if such stockholder approval is required by any federal or state law or

 

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regulation or the rules of any securities exchange or automated quotation system on which the Stock may then be listed or quoted, and the Committee may otherwise, in its discretion, determine to submit other changes to the Plan to stockholders for approval; provided, that, without the consent of an affected Participant, no such Committee action may materially and adversely affect the rights of such Participant under any previously granted and outstanding Award. For purposes of clarity, any adjustments made to Awards pursuant to Section 8 will be deemed not to materially and adversely affect the rights of any Participant under any previously granted and outstanding Award and therefore may be made without the consent of affected Participants.

 

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Exhibit 10.5

Final Form

DPM HOLDCO, LLC

ASSIGNMENT AND ALLOCATION AGREEMENT

This Assignment and Allocation Agreement (this “Agreement”) is made and entered into as of June 6, 2022 (the “Effective Date”) by and between KMF DPM HoldCo, LLC, Chambers DPM HoldCo, LLC, Rock Ridge Royalty Company LLC, Source Energy Leasehold, LP and Permian Mineral Acquisitions, LP (collectively, the “Sponsors”), DPM HoldCo, LLC, a Delaware limited liability company (“DPM”), Sitio Royalties Corp., a Delaware corporation (the “Corporation”), Sitio Royalties Operating Partnership, LP, a Delaware limited partnership (“OpCo”), and [__] (“you”).

WHEREAS, the Sponsors hold all of the issued and outstanding equity interests of DPM;

WHEREAS, DPM entered into that certain Agreement and Plan of Merger, by and among the Corporation, OpCo, Ferrari Merger Sub A LLC, a Delaware limited liability company, and DPM, dated as of January 11, 2022 (the “Merger Agreement”);

WHEREAS, in recognition of your service to DPM, and in order to induce you to continue to serve as an executive officer of the Company (as defined below) and materially contribute to the success of the Company, each Sponsor desires to assign, transfer and convey its right to receive a portion of its Merger Consideration (as defined in the Merger Agreement) set forth opposite such Sponsor’s name on Exhibit A attached hereto to you; and

WHEREAS, for the avoidance of doubt, this assignment, transfer and conveyance is made by the Sponsors and therefore is not governed by the Sitio Royalties Corp. Long Term Incentive Plan or by any other equity compensation plan of the Company or the Corporation.

NOW, THEREFORE, in consideration of and mutual covenants set forth herein and for other valuable consideration hereinafter set forth, the parties hereto agree as follows:

1. Definitions. As used in this Agreement, the following capitalized terms have the meanings set forth below:

Cause” means (A) your material breach of this Agreement or of any other written agreement between you and the Company or any of its affiliates, including your breach of any material representation, warranty or covenant made under any such agreement; (B) your material breach of any policy or code of conduct established by the Company or any of its affiliates and applicable to you; (C) your violation of any law applicable to the workplace (including any law regarding anti-harassment, anti-discrimination, or anti-retaliation); (D) your fraud, theft, dishonesty, gross negligence, willful misconduct, embezzlement, or breach of fiduciary duty related to the Company or any of its affiliates or the performance of your duties hereunder; (E) the conviction or indictment of you for, or plea of guilty or nolo contendere by you to, any felony (or state law equivalent) or any crime involving moral turpitude; or (F) your willful failure or refusal, other than due to Disability, to perform your obligations to the Company or any of its affiliates or to follow any lawful directive from the Company or any of its affiliates, as determined by the board


of directors, members or General Partner, as applicable, of the Company (the “Board”); provided, however, that if your actions or omissions as set forth in this definition are of such a nature that the Board determines that they are curable by you, such actions or omissions must remain uncured thirty (30) days after the Board first provided you written notice of the obligation to cure such actions or omissions.

Class C Shares” means the shares of Class C common stock, par value $0.0001 per share, of the Corporation.

Closing” shall have the meaning assigned to such term in the Merger Agreement.

Company” means DPM; provided, that upon the consummation of the Closing, it shall mean the Corporation with respect to any Class C Shares and OpCo with respect to any OpCo Units, as applicable.

Disability” means a determination by the Company that the Participant is unable to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than 12 months.

DPM Ownership Ratio” means, (i) with respect to KMF DPM HoldCo, LLC, 52.43625%, (ii) with respect to Chambers DPM HoldCo, LLC, 6.81375%, (iii) with respect to Rock Ridge Royalty Company LLC, 19.75000%, (iv) with respect to Source Energy Leasehold, LP, 11.98247%, and (v) with respect to Permian Mineral Acquisitions, LP, 9.01753%.

Good Reason” means (A) a material diminution in your base salary; (B) a material diminution in your authority, duties and responsibilities, taken as a whole; or (C) a material breach by the Sponsors or the Company of any of their respective obligations under this Agreement. Notwithstanding any other provision of this Agreement to the contrary, any assertion by you of a termination for Good Reason shall not be effective unless all of the following conditions are satisfied: (1) the condition described in clause (A), (B), or (C) above giving rise to your termination of employment must have arisen without your consent; (2) you must provide written notice to the Board of the existence of such condition(s) within thirty (30) days after the initial occurrence of such condition(s); (3) the condition(s) specified in such notice must remain uncorrected for thirty (30) days following the Board’s receipt of such written notice; and (4) the date of your termination of employment must occur within sixty (60) days after the initial occurrence of the condition(s) specified in such notice.

OpCo Units” means the common units of OpCo.

2. Assignment. Subject to the conditions set forth below, each Sponsor hereby assigns, transfers and conveys to you the portion of such Sponsor’s right, title and interest in and to the Merger Consideration set opposite such Sponsor’s name on Exhibit A attached hereto and you hereby accept and assume each Sponsor’s right, title and interest in and to such Merger Consideration, in each case subject to certain restrictions thereon (the “Restricted Securities”), and under the terms and conditions set forth herein. The Corporation hereby consents to and waives its rights under the Merger Agreement and any related ancillary documents relating to the transactions contemplated by this Agreement (including Section 2.7 of the Director Designation Agreement (as defined in the Merger Agreement)).

 

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Vesting Schedule:    Except as otherwise expressly set forth herein, the restrictions on one-fourth (1/4) of the number of Restricted Securities assigned hereunder (rounded down to the nearest whole share or unit, if necessary) shall lapse, and such Restricted Securities will become transferable and nonforfeitable, on each of the first four (4) anniversaries of the Effective Date so long as you remain continuously employed by the Company or an affiliate, as applicable, from the Effective Date through each such vesting date.
Resignation for Good Reason following a Change in Control    Notwithstanding anything contained herein to the contrary, upon the termination of your employment with the Company or an affiliate by you for Good Reason that occurs following a Change in Control (as defined in the Sitio Royalties Corp. Long Term Incentive Plan, as amended from time to time), the restrictions on all of the Restricted Securities assigned pursuant to this Agreement will expire and the Restricted Securities will become transferable and nonforfeitable on the date of your termination of employment for Good Reason.
Termination of Employment without Cause    Notwithstanding anything contained herein to the contrary, upon the termination of your employment with the Company or an affiliate by the Company or such affiliate without Cause, the restrictions on all of the Restricted Securities assigned pursuant to this Agreement will expire and the Restricted Securities will become transferable and nonforfeitable on the date of your termination of employment without Cause.
Death; Disability    Notwithstanding anything contained herein to the contrary, upon the termination of your employment with the Company or an affiliate due to your death or Disability, the restrictions on all of the Restricted Securities assigned pursuant to this Agreement will expire and the Restricted Securities will become transferable and nonforfeitable on the date of your termination due to death or Disability.

3. Escrow of Restricted Securities. The Restricted Securities shall be evidenced in the manner deemed appropriate by the Company, as applicable. You may be issued a certificate or certificates representing the Restricted Securities that you shall retain until the restrictions on such Restricted Securities expire as contemplated in Sections 2 and 6 of this Agreement or the Restricted Securities are forfeited as described in Sections 5 and 7 of this Agreement. If the Restricted Securities are evidenced by a certificate or certificates, you shall execute one or more stock powers in blank for those certificates and deliver those stock powers to the Sponsors or the Company, as applicable. The Company shall hold the Restricted Securities and the related stock powers pursuant to the terms of this Agreement, if applicable, until such time as (a) a certificate or certificates for the Restricted Securities are delivered to you, (b) the Restricted Securities are otherwise transferred to you free of restrictions, or (c) the Restricted Securities are canceled and forfeited pursuant to this Agreement.

 

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4. Ownership of Restricted Securities. You will be entitled to all the rights of absolute ownership of the Restricted Securities, including the right to vote those Restricted Securities and, with respect to the Restricted Securities that are OpCo Units, receive all distributions paid with respect to such Restricted Securities, subject, however, to the terms, conditions and restrictions set forth in this Agreement; provided, however, that each distribution payment will be made no later than the 30th day following the date such distribution is made to OpCo unitholders generally. For the avoidance of doubt, you will receive any distributions paid with respect to such OpCo Units, including prior to the date on which the restrictions on the Restricted Securities expire as contemplated in Sections 2 and 6 of this Agreement; provided, however, that distributions paid with respect to forfeited Restricted Securities shall be paid to the Sponsors (or their transferees) in accordance with their ownership of such forfeited Restricted Securities following issuance to the Sponsors in accordance with their respective DPM Ownership Ratios.

5. Restrictions; Forfeiture. The Restricted Securities are restricted in that they may not be sold, transferred, or otherwise alienated or hypothecated until these restrictions are removed or expire as contemplated in Sections 2 and 6 of this Agreement. The Restricted Securities are also restricted in the sense that they may be forfeited. You hereby agree that if the Restricted Securities are forfeited, as provided in Section 7, the Company shall, or shall cause the applicable transfer agent to, issue to the Sponsors pro rata in accordance with their respective DPM Ownership Ratios a number of OpCo Units and Class C Shares equal to the number of Restricted Securities forfeited; provided, that each Sponsor may elect, in its sole discretion, to waive its right to receive such OpCo Units and Class C Shares, in which case such OpCo Units and Class C Shares shall be forfeited to the Company.

6. Expiration of Restrictions and Risk of Forfeiture. The restrictions on the Restricted Securities assigned pursuant to this Agreement will expire and the Restricted Securities will become transferable and nonforfeitable as set forth in Section 2 of this Agreement, provided that you remain in the employ of, or a service provider to, the Company or any of its affiliates until the applicable dates set forth therein.

7. Forfeiture. Except as otherwise provided in Section 2, if your employment or service relationship with the Company or its affiliate is terminated for any reason, then those Restricted Securities for which the restrictions have not lapsed as of the date of termination shall become null and void and those Restricted Securities shall be forfeited for no consideration. The Restricted Securities for which the restrictions have lapsed as of the date of such termination shall not be forfeited.

8. Leave of Absence. With respect to this Agreement, the Company may, in its sole discretion, determine that if you are on leave of absence for any reason you will be considered to still be in the employ of, or providing services for, the Company, provided that rights to the Restricted Securities during a leave of absence will be limited to the extent to which those rights were earned or vested when the leave of absence began.

 

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9. Company Action. Upon the expiration of the restrictions on the Restricted Securities as contemplated in Section 6 of this Agreement, the Restricted Securities will become transferable and nonforfeitable and the Company shall take all necessary action to reflect this (including causing the removal of any restrictive legend), subject to receipt by the Company of any required tax withholding pursuant to Section 10. The value of such Restricted Securities shall not bear any interest owing to the passage of time.

10. Payment of Taxes. To the extent that the receipt, vesting or settlement of the Restricted Securities results in compensation income or wages to you for federal, state, local and/or foreign tax purposes, you shall make arrangements satisfactory to the Company for the satisfaction of obligations for the payment of withholding taxes and other tax obligations relating to the Restricted Securities, which arrangements include the delivery of cash or cash equivalents, Class C Shares and/or OpCo Units (including previously owned Class C Shares and/or OpCo Units, net settlement, net early settlement, a broker-assisted sale, or other cashless withholding or reduction of the amount of Class C Shares and/or OpCo Units otherwise issuable or delivered pursuant to the Restricted Securities), other property, or any other legal consideration the Board deems appropriate. If such tax obligations are satisfied through net settlement, net early settlement or the surrender of previously owned Class C Shares and/or OpCo Units, the maximum number of Class C Shares and/or OpCo Units that may be so withheld (or surrendered) shall be the number of Class C Shares and/or OpCo Units that have an aggregate Fair Market Value (as defined below) on the date of withholding or surrender equal to the aggregate amount of such tax liabilities determined based on the greatest withholding rates for federal, state, local and/or foreign tax purposes, including payroll taxes, that may be utilized without creating adverse accounting treatment for the Sponsors or the Company with respect to the Restricted Securities, as determined by the Board. You acknowledge that there may be adverse tax consequences upon the receipt, vesting or settlement of the Restricted Securities or disposition of the underlying shares and/or units and that you have been advised, and hereby are advised, to consult a tax advisor. You represent that you are in no manner relying on the Board, the Sponsors, DPM, the Corporation or OpCo or any of their respective affiliates or any of their respective managers, directors, officers, employees or authorized representatives (including, without limitation, attorneys, accountants, consultants, bankers, lenders, prospective lenders and financial representatives) for tax advice or an assessment of such tax consequences.

11. Acknowledgement. You acknowledge and agree that (a) you are not relying upon any determination by the Sponsors, DPM, the Corporation or OpCo, their respective affiliates, or any of their respective employees, directors, officers, attorneys, or agents (collectively, the “Company Parties”) of the Fair Market Value (as defined below) of the Class C Shares and OpCo Units on the Effective Date, (b) you are not relying upon any written or oral statement or representation of the Company Parties regarding the tax effects associated with your execution of this Agreement and your receipt, holding, and vesting of the Restricted Securities, and (c) in deciding to enter into this Agreement, you are relying on your own judgment and the judgment of the professionals of your choice with whom you have consulted. You hereby release, acquit and forever discharge the Company Parties from all actions, causes of actions, suits, debts, obligations, liabilities, claims, damages, losses, costs, and expenses of any nature whatsoever, known or unknown, on account of, arising out of, or in any way related to the tax effects associated with your execution of the Agreement and your receipt, holding and exercise of the Restricted Securities. For purposes of this Agreement, “Fair Market Value” means, as of any specified date, the amount determined by the Board in its discretion in such manner as it deems appropriate, taking into consideration all factors the Board deems appropriate including without limitation.

 

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12. Compliance with Securities Law. Notwithstanding any provision of this Agreement to the contrary, the issuance of Class C Shares and/or OpCo Units (including the Restricted Securities) will be subject to compliance with all applicable requirements of federal, state, or foreign law with respect to such securities and with the requirements of any stock exchange or market system upon which the Class C Shares and/or OpCo Units (or any security into which such securities may be exchanged) may then be listed. No Class C Shares and/or OpCo Units will be issued hereunder if such issuance would constitute a violation of any applicable federal, state, or foreign securities laws or other law or regulations or the requirements of any stock exchange or market system upon which the Class C Shares and/or OpCo Units (or any security into which such securities may be exchanged) may then be listed. In addition, Class C Shares and OpCo Units will not be issued hereunder unless (a) a registration statement under the Securities Act of 1933, as amended (the “Act”), is at the time of issuance in effect with respect to the shares issued or (b) in the opinion of legal counsel to the Company, the shares issued may be issued in accordance with the terms of an applicable exemption from the registration requirements of the Act. The inability of the Company to obtain from any regulatory body having jurisdiction the authority, if any, deemed by the Company’s legal counsel to be necessary to the lawful issuance and sale of any shares and units subject to this Agreement will relieve the Company of any liability in respect of the failure to issue such shares as to which such requisite authority has not been obtained. As a condition to any issuance hereunder, the Company may require you to satisfy any qualifications that may be necessary or appropriate to evidence compliance with any applicable law or regulation and to make any representation or warranty with respect to such compliance as may be requested by the Company. From time to time, the Board and appropriate officers of the Company are authorized to undertake (or cause to be undertaken) the actions necessary and appropriate to file required documents with governmental authorities, stock exchanges, and other appropriate persons to make Class C Shares and/or OpCo Units available for issuance.

13. Legends. The Company or OpCo, as applicable, shall place, or cause to be placed, legends referencing the restrictions imposed on the Restricted Securities pursuant to this Agreement on all certificates (or book-entry notations) representing Restricted Securities issued with respect to this Agreement.

14. No Right to Continued Employment. Nothing in this Agreement confers upon you the right to remain employed by the Company or any of its affiliates, or interfere in any way with the rights of the Company or such affiliate to terminate your employment relationship at any time.

15. Furnish Information. You agree to furnish to the Sponsors or the Company, as applicable, all information requested by the Sponsors or the Company to enable it to comply with any reporting or other requirements imposed upon the Sponsors or the Company by or under any applicable statute or regulation.

16. Remedies. The parties to this Agreement shall be entitled to recover from each other reasonable attorneys’ fees incurred in connection with the successful enforcement of the terms and provisions of this Agreement whether by an action to enforce specific performance or for damages for its breach or otherwise.

 

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17. No Liability for Good Faith Determinations. None of the Sponsors, DPM, the Corporation or OpCo or the members of the Board shall be liable for any act, omission or determination taken or made in good faith with respect to this Agreement or the Restricted Securities assigned hereunder.

18. Execution of Receipts and Releases. Any payment of cash or any issuance or transfer of shares of Class C Shares and/or OpCo Units or other property to you, or to your legal representative, heir, legatee or distributee, in accordance with the provisions hereof, shall, to the extent thereof, be in full satisfaction of all claims of such persons hereunder. The Company may require you or your legal representative, heir, legatee, or distributee, as a condition precedent to such payment or issuance, to execute a release and receipt therefor in such form as it shall determine.

19. No Guarantee of Interests. None of the Sponsors, DPM, the Corporation or OpCo or the members of the Board guarantee the Class C Shares or OpCo Units of the Company from loss or depreciation.

20. Notice. All notices required or permitted under this Agreement must be in writing and personally delivered or sent by mail and shall be deemed to be delivered on the date on which it is actually received by the person to whom it is properly addressed or if earlier the date it is sent via certified United States mail.

21. Waiver of Notice. Any person entitled to notice hereunder may waive such notice in writing.

22. Information Confidential. As partial consideration for the assignment of the Restricted Securities hereunder, you hereby agree to keep confidential all information and knowledge, except that which has been disclosed in any public filings required by law, that you have relating to the terms and conditions of this Agreement; provided, however, that such information may be disclosed as required by law and may be given in confidence to your spouse and tax and financial advisors.

23. Successors. This Agreement shall be binding upon you, your legal representatives, heirs, legatees, and distributees, and upon the Sponsors, DPM, the Corporation and OpCo, and their respective successors, and assigns.

24. Severability. If any provision of this Agreement is held to be illegal or invalid for any reason, the illegality or invalidity shall not affect the remaining provisions hereof, but such provision shall be fully severable and this Agreement shall be construed and enforced as if the illegal or invalid provision had never been included herein.

25. Headings. The titles and headings of Sections are included for convenience of reference only and are not to be considered in construction of the provisions hereof.

26. Governing Law. ALL QUESTIONS ARISING WITH RESPECT TO THE PROVISIONS OF THIS AGREEMENT SHALL BE DETERMINED BY APPLICATION OF THE LAWS OF DELAWARE, WITHOUT GIVING ANY EFFECT TO ANY CONFLICT OF LAW PROVISIONS THEREOF, EXCEPT TO THE EXTENT DELAWARE STATE LAW IS

 

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PREEMPTED BY FEDERAL LAW. THE OBLIGATION OF THE COMPANY TO SELL AND DELIVER CLASS C SHARES AND/OR OPCO UNITS HEREUNDER IS SUBJECT TO APPLICABLE LAWS AND TO THE APPROVAL OF ANY GOVERNMENTAL AUTHORITY REQUIRED IN CONNECTION WITH THE AUTHORIZATION, ISSUANCE, SALE, OR DELIVERY OF SUCH CLASS C SHARES AND/OR OPCO UNITS.

27. Termination. This Agreement shall automatically terminate upon the termination of the Merger Agreement.

28. Authority of the Board; Amendment. This Agreement and the Restricted Securities assigned hereunder shall be administered by the Board. The Board shall have the authority, in its sole and absolute discretion, to (a) adopt, amend, and rescind administrative and interpretive rules and regulations relating to this Agreement; (b) accelerate the time of vesting of the Restricted Securities; (c) construe this Agreement and the Restricted Securities; (d) make determinations of the Fair Market Value of Class C Shares and OpCo Units subject to this Agreement; (e) delegate its duties under this Agreement to such agents as it may appoint from time to time; (f) terminate, modify, or amend this Agreement, provided that, no amendment or termination may decrease your rights inherent in this Agreement prior to such amendment without your express written permission except to the extent such amendment is necessary to comply with applicable laws and regulations and to conform the provisions of this Agreement to any change thereto; and (g) make all other determinations, perform all other acts, and exercise all other powers and authority necessary or advisable for administering this Agreement, including the delegation of those ministerial acts and responsibilities as appropriate. The Board may correct any defect, supply any omission, or reconcile any inconsistency in this Agreement in the manner and to the extent it deems necessary or desirable to carry the Agreement into effect, and the Board shall be the sole and final judge of that necessity or desirability. The determinations of the Board on the matters referred to in this Section 28 shall be final and conclusive.

 

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KMF DPM HOLDCO, LLC
By:    
Name:  
Title:  

 

CHAMBERS DPM HOLDCO, LLC
By:    
Name:  
Title:  

 

ROCK RIDGE ROYALTY COMPANY LLC
By:    
Name:  
Title:  

 

SOURCE ENERGY LEASEHOLD, LP
By: Source Energy Operating, LP, its general partner
By: Source Energy Manager, LLC, its sole member
By:    
Name:  
Title:  
PERMIAN MINERAL ACQUISITIONS, LP
By: Permian Mineral Acquisitions GP, LLC, its general partner
By:    
Name:  
Title:  

SIGNATURE PAGE TO

ASSIGNMENT AND AWARD AGREEMENT


DPM HOLDCO, LLC
By:    
Name:  
Title:  
SITIO ROYALTIES CORP.
By:    
Name:  
Title:  
SITIO ROYALTIES OPERATING PARTNERSHIP, LP
By: Sitio Royalties GP, LLC, its general partner
By:    
Name:  
Title:  

SIGNATURE PAGE TO

ASSIGNMENT AND AWARD AGREEMENT


ACCEPTED AND AGREED:

 

[insert name of Grantee]
Date:                                                                          

SIGNATURE PAGE TO

ASSIGNMENT AND AWARD AGREEMENT


Exhibit A

 

Sponsor

  

Merger Consideration

KMF DPM HoldCo, LLC   

Chambers DPM HoldCo, LLC

  
Rock Ridge Royalty Company LLC   
Source Energy Leasehold, LP   
Permian Mineral Acquisitions, LP   

Exhibit 10.6

SITIO ROYALTIES CORP.

SEVERANCE PLAN AND SUMMARY PLAN DESCRIPTION

1. Purpose and Effective Date. Sitio Royalties Corp., a Delaware corporation (the “Company”) has adopted this Severance Plan (this “Plan”) to provide for the potential payment of severance benefits to Eligible Individuals (as defined below) in the event of certain terminations of employment as described herein. The Plan was approved by the Board of Directors of the Company (the “Board”) to be effective as of June 7, 2022 (the “Effective Date”).

2. ERISA and Tax Compliance. The Plan is intended to be a “severance pay arrangement” within the meaning of Section 3(2)(B)(i) of ERISA that is excepted from the definitions of “employee pension benefit plan” and “pension plan” set forth under Section 3(2) of ERISA, and is intended to meet the descriptive requirements of a plan constituting a “severance pay plan” within the meaning of regulations published by the Secretary of Labor at Title 29, Code of Federal Regulations §2510.3-2(b). The Plan is not intended to satisfy the qualification requirements of Code Section 401, but is intended to comply with the requirements of Code Section 409A and the Treasury regulations and guidance issued thereunder. This Plan document also constitutes a summary plan description with respect to the Plan. This Plan is a welfare program under the Company’s health and welfare plan.

3. Definitions. For purposes of this Plan, the terms listed below shall have the meanings specified herein:

(a) “Administrator” means the Board or a committee appointed by the Board to administer this Plan.

(b) “Affiliate” means any person that directly or indirectly through one or more intermediaries, controls, is controlled by, or is under common control with, the Company and any predecessor to any such entity; provided¸ however, that a natural person shall not be considered an Affiliate.

(c) “Base Salary” means the amount an Eligible Individual is entitled to receive as regular hourly wages (considering regularly scheduled workweeks, and excluding any overtime or premium pay) or base salary on an annualized basis, calculated as of immediately prior to the Termination Date or, if greater, before giving effect to any reduction not consented to by the Eligible Individual.

(d) “Board” means the Board of Directors of the Company.

(e) “Business” means, with respect to an Eligible Individual, the business and operations that are the same or similar to those performed by the Company and any other member of the Company Group for which such Eligible Individual provides services or about which such Eligible Individual obtains Confidential Information during such Eligible Individual’s employment with any member of the Company Group, which business and operations include the acquisition and management of mineral and royalty interests in the Permian Basin.


(f) “Business Opportunity” means, with respect to an Eligible Individual, any commercial, investment or other business opportunity relating to the Business (as such term is defined in relation to such Eligible Individual).

(g) “Cause” means one or more of the following events: (i) an Eligible Individual’s material breach of this Plan (including an Eligible Individual’s violation of any of the covenants set forth in Section 9) or of any other written agreement between such Eligible Individual and one or more members of the Company Group, including such Eligible Individual’s breach of any material representation, warranty or covenant made under any such agreement; (ii) an Eligible Individual’s material breach of any policy or code of conduct established by a member of the Company Group and applicable to such Eligible Individual; (iii) an Eligible Individual’s violation of any law applicable to the workplace (including any law regarding anti-harassment, anti-discrimination, or anti-retaliation); (iv) an Eligible Individual’s fraud, theft, dishonesty, gross negligence, willful misconduct, embezzlement, or breach of fiduciary duty related to any member of the Company Group or the performance of such Eligible Individual’s duties hereunder; (v) the conviction or indictment of an Eligible Individual for, or plea of guilty or nolo contendere by such Eligible Individual to, any felony (or state law equivalent) or any crime involving moral turpitude; or (vi) an Eligible Individual’s willful failure or refusal, other than due to Disability, to perform such Eligible Individual’s obligations to the Company or a member of the Company Group or to follow any lawful directive from the Company or a member of the Company Group, as determined by the Administrator; provided, however, that if an Eligible Individual’s actions or omissions as set forth in this Section 3(g) are of such a nature that the Administrator determines that they are curable by such Eligible Individual, such actions or omissions must remain uncured thirty (30) days after the Administrator first provided such Eligible Individual written notice of the obligation to cure such actions or omissions.

(h) “CEO” means the Chief Executive Officer of the Company.

(i) “Change in Control” means the consummation of any of the following events after the Effective Date:

(i) any Person or any group of Persons acting together which would constitute a “group” for purposes of Section 13(d) of the Exchange Act (excluding a corporation or other entity owned, directly or indirectly, by the stockholders of the Company in substantially the same proportions as their ownership of stock of the Company) is or becomes the “beneficial owner,” as defined in Rule 13d-3 under the Exchange Act, directly or indirectly, of securities of the Company representing more than 50% of the combined voting power of the Company’s then outstanding voting securities;

(ii) individuals who constitute the Incumbent Board cease for any reason to constitute at least a majority of the Board;

(iii) there is consummated a merger or consolidation of the Company with any other corporation or other entity, and, immediately after the consummation of such merger or consolidation, the voting securities of the Company immediately prior to such merger or consolidation do not continue to represent or are not converted into more than 50% of the combined voting power of the then-outstanding voting securities of the Person resulting from such merger or consolidation or, if the surviving company is a subsidiary, the ultimate parent thereof; or

 

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(iv) the stockholders of the Company approve a plan of complete liquidation or dissolution of the Company or there is consummated an agreement or series of related agreements for the sale or other disposition, directly or indirectly, by the Company of all or substantially all of the Company’s assets, other than such sale or other disposition by the Company of all or substantially all of the Company’s assets to an entity, at least 50% of the combined voting power of the voting securities of which are owned by stockholders of the Company in substantially the same proportions as their ownership of the Company immediately prior to such sale, provided that, in all such cases, the transactions contemplated by the provisions above are ultimately consummated.

Notwithstanding the foregoing, except with respect to clause (ii) above, a “Change in Control” shall not be deemed to have occurred by virtue of the consummation of any transaction or series of integrated transactions immediately following which the record holders of the shares of the Company immediately prior to such transaction or series of transactions continue to have substantially the same proportionate ownership in, and own substantially all of the shares of, an entity which owns, either directly or through a subsidiary, all or substantially all of the assets of the Company immediately following such transaction or series of transactions.

(j) “Change in Control Period” means the period beginning on the date that a Change in Control occurs and ending on the date that is six (6) months following the date that a Change in Control occurs.

(k) “CIC Termination” means a Qualifying Termination that occurs during the Change in Control Period.

(l) “Code” means the Internal Revenue Code of 1986, as amended.

(m) “Company Group” means the Company and its direct and indirect subsidiaries.

(n) “Confidential Information” means all trade secrets, non-public information, designs, ideas, concepts, improvements, product developments, discoveries and inventions, whether patentable or not, that are conceived, made, developed or acquired by or disclosed to an Eligible Individual, individually or in conjunction with others, during the period that he or she is employed or engaged by the Company or any other member of the Company Group (whether during business hours or otherwise and whether on the Company’s premises or otherwise) that relate to any member of the Company Group’s businesses or properties, products or services (including all such information relating to corporate opportunities, operations, future plans, methods of doing business, business plans, strategies for developing business and market share, research, financial and sales data, pricing terms, evaluations, opinions, interpretations, acquisition prospects, the identity of customers or acquisition targets or their requirements, the identity of key contacts within customers’ organizations or within the organization of acquisition prospects, or marketing and merchandising techniques, prospective names and marks). For purposes of this Plan, Confidential Information shall not include any information that (i) is or

 

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becomes generally available to the public other than as a result of a disclosure or wrongful act of such Eligible Individual or any of his or her agents; (ii) was available to such Eligible Individual on a non-confidential basis before its disclosure by a member of the Company Group; or (iii) becomes available to such Eligible Individual on a non-confidential basis from a source other than a member of the Company Group; provided, however, that such source is not bound by a confidentiality agreement with, or other obligation with respect to confidentiality to, a member of the Company Group.

(o) “Death/Disability Termination” means the termination of an Eligible Individual’s employment due to death or Disability.

(p) “Disability” means a determination by the Administrator that an Eligible Individual is unable to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than 12 months.

(q) “Eligible Individual” means an employee of the Company eligible to receive the benefits described in this Plan, as designated in writing by the Administrator; provided, however, that (i) any individual who has a written employment or severance agreement with the Company that provides for potential severance benefits (other than any benefits pursuant to this Plan) shall not be an Eligible Individual under this Plan; and (ii) in order to be an Eligible Individual, such employee must sign and return to the Company, in the time designated by the Administrator, a Participation Agreement.

(r) “ERISA means the Employee Retirement Income Security Act of 1974, as amended.

(s) “Exchange Act” means the Securities Exchange Act of 1934, as amended.

(t) “Good Reason” means (i) a material diminution in an Eligible Individual’s Base Salary; (ii) a material diminution in an Eligible Individual’s authority, duties and responsibilities, taken as a whole; or (iii) a material breach by the Company of any of its obligations under this Plan. Notwithstanding the foregoing provisions of this Section 3(t) or any other provision of this Plan to the contrary, any assertion by an Eligible Individual of a termination for Good Reason shall not be effective unless all of the following conditions are satisfied: (A) the condition described in clause (i), (ii), or (iii) above giving rise to the Eligible Individual’s termination of employment must have arisen without the Eligible Individual’s consent; (B) the Eligible Individual must provide written notice to the Administrator of the existence of such condition(s) within thirty (30) days after the initial occurrence of such condition(s); (C) the condition(s) specified in such notice must remain uncorrected for thirty (30) days following the Administrator’s receipt of such written notice; and (D) the date of such Eligible Individual’s termination of employment must occur within sixty (60) days after the initial occurrence of the condition(s) specified in such notice.

 

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(u) “Incumbent Board” means the portion of the Board constituted of the individuals who are members of the Board as of the Effective Date and any other individual who becomes a director of the Company after the Effective Date and whose election or appointment by the Board or nomination for election by the Company’s stockholders was approved by a vote of at least two-thirds of the directors then comprising the Incumbent Board, but excluding, for this purpose, any such individual whose initial assumption of office occurs as a result of an actual or threatened election contest with respect to the election or removal of directors or other actual or threatened solicitation of proxies or consents by or on behalf of a Person other than the Incumbent Board.

(v) “LTIP” means the Sitio Royalties Corp. Long Term Incentive Plan, as amended from time to time, together with any successor equity incentive plans adopted by the Company.

(w) “Market Area” means each geographic area or market where or with respect to which the Company or any other member of the Company Group conducts or has specific plans to conduct the Business on or at any time during the twelve (12) month period prior to the Termination Date.

(x) “Participation Agreement” means the participation agreement delivered to an Eligible Individual by the Administrator prior to his or her becoming a participant in this Plan evidencing such Eligible Individual’s agreement to participate in this Plan and to comply with the terms, conditions and restrictions within the Plan.

(y) “Person” means any individual, corporation, firm, partnership, joint venture, limited liability company, estate, trust, business association, organization, governmental entity or other entity.

(z) “Qualifying Termination” means (i) the termination of an Eligible Individual’s employment or service relationship by the Company other than due to death, Disability or for Cause or (ii) the termination of an Eligible Individual’s employment or service relationship due to a resignation by the Eligible Individual for Good Reason.

(aa) “Termination Date” means the date that an Eligible Individual has a “separation from service” as defined under Code Section 409A and applicable guidance thereunder.

4. Eligibility; Plan Benefits. The Eligible Individuals designated by the Administrator are eligible to receive the benefits described below:

(a) Qualifying Termination. In the event of (x) a Qualifying Termination that occurs outside of the Change in Control Period or (y) a Death/Disability Termination, the Eligible Individual shall, subject to compliance with Sections 5 and 9, be entitled to receive the following benefits:

(i) A payment (a “Severance Payment”) in an amount equal to:

(A) in the case of the CEO, twenty-four (24) months of Base Salary; or

 

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(B) in the case of an Eligible Individual other than the CEO, eighteen (18) months of Base Salary.

(ii) All unvested equity-based awards granted under the LTIP that are held by the Eligible Individual as of immediately prior to the Termination Date shall immediately become fully vested as of the Termination Date; provided, however, that with respect to any equity-based award that is subject to performance-based vesting conditions, any service requirement applicable to such equity-based award shall be deemed satisfied as to a portion of such award calculated based on the number of days the Eligible Individual was employed by or provided services to the Company between the applicable date of grant and the Termination Date and such pro-rata portion shall remain outstanding and, subject to the satisfaction of applicable performance metrics calculated through the end of the applicable performance period, be eligible for settlement following the end of such performance period.

(b) CIC Termination. In the event of a CIC Termination, the Eligible Individual shall, subject to compliance with Sections 5 and 9, be entitled to receive the following benefits (which are in lieu of the benefits described in Section 4(a) above):

(i) A payment (a “CIC Severance Payment”) in an amount (subject to Section 4(e)(iii)) equal to:

(A) in the case of the CEO, thirty-six (36) months of Base Salary; or

(B) in the case of an Eligible Individual other than the CEO, twenty-four (24) months of Base Salary.

(ii) All unvested equity-based awards granted under the LTIP that are held by the Eligible Individual as of immediately prior to the Termination Date shall immediately become fully vested as of the Termination Date; provided, however, that with respect to any equity-based award that is subject to performance-based vesting conditions, such equity-based award shall be calculated and settled, without proration, subject to and based on the greater of (x) target performance or (y) actual performance and achievement of the applicable performance metrics calculated through the date of the Change in Control.

(c) Payment of Severance Payment or CIC Severance Payment.

(i) Any Severance Payment will be divided into substantially equal installments paid over the twenty-four (24)-month period (in the case of the CEO) or the eighteen (18)-month period (in the case of an Eligible Individual other than the CEO) beginning on the Company’s first regularly scheduled pay date that is on or after the date that is sixty (60) days after the Termination Date; provided, however, that to the extent, if any, that the aggregate amount of the installments of the Severance Payment that would otherwise be paid pursuant to the preceding provisions of this Section 4(c)(i) after March 15 of the calendar year following the calendar year in which the Termination Date occurs (the “Applicable March 15”) exceeds the maximum exemption amount under Treasury Regulation Section 1.409A-1(b)(9)(iii)(A), then such excess shall be paid to the Eligible Individual in a lump sum on the Applicable March 15 (or the first business day preceding the Applicable March 15 if the Applicable March 15 is not a business day) and the installments of the Severance Payment payable after the Applicable March 15 shall be reduced by such excess (beginning with the installment first payable after the Applicable March 15 and continuing with the next succeeding installment until the aggregate reduction equals such excess).

 

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(ii) With respect to all Eligible Individuals, any CIC Severance Payment will paid in a lump sum on the Company’s first regularly scheduled pay date that is on or after the date that is sixty (60) days after the Termination Date.

5. Release. As a condition to the payment by the Company of any of the amounts and benefits due under Section 4 above, the Eligible Individual shall: (a) execute on or before the Release Expiration Date (as defined below), and not revoke within any time provided by the Company to do so, a release of all claims in a form acceptable to the Company (the “Release”), which Release shall release each member of the Company Group and their respective Affiliates, and the foregoing entities’ respective shareholders, members, partners, officers, managers, directors, fiduciaries, employees, representatives, agents and benefit plans (and fiduciaries of such plans) from any and all claims, including any and all causes of action arising out of the Eligible Individual’s employment with the Company and any other member of the Company Group or the termination of such employment, but excluding all claims to severance payments or benefits that the Eligible Individual may have under this Plan ; and (b) abide by the terms of Section 9. As used herein, the “Release Expiration Date” is that date that is twenty-one (21) days following the date upon which the Company delivers the Release to an Eligible Individual (which shall occur no later than seven (7) days after the Termination Date) or, in the event that such termination of employment is “in connection with an exit incentive or other employment termination program” (as such phrase is defined in the Age Discrimination in Employment Act of 1967), the date that is forty-five (45) days following such delivery date.

6. No Mitigation. An Eligible Individual shall not be required to mitigate the amount of any payment or benefit provided for in this Plan by seeking other employment or otherwise, nor shall the amount of any payment or benefit provided for in this Plan be reduced by any compensation or benefit earned by the Eligible Individual as the result of employment by another employer or by retirement benefits. Subject to the foregoing, the benefits under this Plan are in addition to any other benefits to which an Eligible Individual is otherwise entitled.

7. Terminations for Cause or Voluntary Resignation. If an Eligible Individual’s employment is terminated by the Company for Cause or by the Eligible Individual due to a voluntary resignation, the Eligible Individual shall not be entitled to any severance payments or benefits under this Plan.

8. Certain Excise Taxes. Notwithstanding anything to the contrary in this Plan, if an Eligible Individual is a “disqualified individual” (as defined in Section 280G(c) of the Code), and the payments and benefits provided for in this Plan, together with any other payments and benefits which such Eligible Individual has the right to receive from the Company or any of its Affiliates, would, either separately or in the aggregate, constitute a “parachute payment” (as defined in Section 280G(b)(2) of the Code), then the payments and benefits provided for in this Plan shall be either (a) reduced (but not below zero) so that the present value of such total amounts and benefits received by such Eligible Individual from the Company and its Affiliates shall be one dollar

 

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($1.00) less than three times such Eligible Individual’s “base amount” (as defined in Section 280G(b)(3) of the Code) and so that no portion of such amounts and benefits received by such Eligible Individual shall be subject to the excise tax imposed by Section 4999 of the Code or (b) paid in full, whichever produces the better net after-tax position to such Eligible Individual (taking into account any applicable excise tax under Section 4999 of the Code and any other applicable taxes). The reduction of payments and benefits hereunder, if applicable, shall be made by reducing, first, payments or benefits to be paid in cash hereunder in the order in which such payment or benefit would be paid or provided (beginning with such payment or benefit that would be made last in time and continuing, to the extent necessary, through to such payment or benefit that would be made first in time) and, then, reducing any benefit to be provided in-kind hereunder in a similar order. The determination as to whether any such reduction in the amount of the payments and benefits provided hereunder is necessary shall be made by the Company in good faith. If a reduced payment or benefit is made or provided and through error or otherwise that payment or benefit, when aggregated with other payments and benefits from the Company (or its Affiliates) used in determining if a “parachute payment” exists, exceeds one dollar ($1.00) less than three times such Eligible Individual’s base amount, then such Eligible Individual shall be required to immediately repay such excess to the Company upon notification that an overpayment has been made. Nothing in this Section 8 shall require the Company to be responsible for, or have any liability or obligation with respect to, such Eligible Individuals’ excise tax liabilities under Section 4999 of the Code.

9. Confidentiality; Non-Competition; Non-Solicitation.

(a) Following the time that an Eligible Individual becomes a participant in the Plan, he or she will be provided with, and will have access to, Confidential Information. Both during the time that an Eligible Individual participates in this Plan and thereafter, except as expressly permitted by this Plan or by directive of the Administrator, such Eligible Individual shall not disclose any Confidential Information to any person or entity and shall not use any Confidential Information except for the benefit of the Company Group. By becoming an Eligible Individual, each Eligible Individual acknowledges and agrees that he or she would inevitably use and disclose Confidential Information in violation of this Section 9(a) if he or she were to violate any of the covenants set forth in the other portions of this Section 9. The Eligible Individual shall follow all Company Group policies and protocols regarding the security of all documents and other materials containing Confidential Information (regardless of the medium on which Confidential Information is stored). The covenants of this Section 9(a) shall apply to all Confidential Information, whether now known or later to become known to an Eligible Individual during the period that he or she is employed by or affiliated with the Company or any other member of the Company Group.

(b) Notwithstanding any provision of Section 9(a) to the contrary, Eligible Individuals may make the following disclosures and uses of Confidential Information:

(i) disclosures to employees of a member of the Company Group who have a need to know the information in connection with the businesses of the Company Group;

(ii) disclosures to customers and suppliers when, in the reasonable and good faith belief of such Eligible Individual, such disclosure is in connection with the Eligible Individual’s performance of the Eligible Individual’s duties and is in the best interests of the Company Group;

 

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(iii) disclosures and uses that are approved in writing by the Administrator; or

(iv) disclosures to a person or entity that has (x) been retained by a member of the Company Group to provide services to one or more members of the Company Group and (y) agreed in writing to abide by the terms of a confidentiality agreement.

(c) Notwithstanding the foregoing, nothing in this Plan shall prohibit or restrict an Eligible Individual from lawfully: (i) initiating communications directly with, cooperating with, providing information to, causing information to be provided to, or otherwise assisting in an investigation by, any governmental authority regarding a possible violation of any law; (ii) responding to any inquiry or legal process directed to such Eligible Individual from any such governmental authority (including the U.S. Securities and Exchange Commission); (iii) testifying, participating or otherwise assisting in any action or proceeding by any such governmental authority relating to a possible violation of law; or (iv) making any other disclosures that are protected under the whistleblower provisions of any applicable law. Additionally, pursuant to the federal Defend Trade Secrets Act of 2016, an individual shall not be held criminally or civilly liable under any federal or state trade secret law for the disclosure of a trade secret that: (A) is made (1) in confidence to a federal, state or local government official, either directly or indirectly, or to an attorney and (2) solely for the purpose of reporting or investigating a suspected violation of law; (B) is made to the individual’s attorney in relation to a lawsuit for retaliation against the individual for reporting a suspected violation of law; or (C) is made in a complaint or other document filed in a lawsuit or proceeding, if such filing is made under seal. Nothing in this Plan requires an Eligible Individual to obtain prior authorization before engaging in any conduct described in this paragraph, or to notify the Company that he or she has engaged in any such conduct.

(d) The Company shall provide Eligible Individuals access to Confidential Information for use only during the period of such Eligible Individual’s employment or engagement by the Company or another member of the Company Group, and in consideration of the Company providing such Eligible Individual with access to Confidential Information and as a condition to such Eligible Individual’s participation in this Plan, each Eligible Individual voluntarily agrees to the covenants set forth in this Section 9. Each Eligible Individual agrees and acknowledges that the limitations and restrictions set forth herein, including geographical and temporal restrictions on certain competitive activities, are reasonable in all respects, do not interfere with public interests, will not cause such Eligible Individual undue hardship, and are material and substantial parts of this Plan intended and necessary to prevent unfair competition and to protect the Company Group’s confidential information, goodwill and legitimate business interests.

(e) During the period in which the Eligible Individual is employed by any member of the Company Group and continuing for a period of three (3) months following the date that the Eligible Individual is no longer employed by any member of the Company Group, each Eligible Individual shall not, without the prior written approval of the Administrator, directly or indirectly, for such Eligible Individual or on behalf of or in conjunction with any other person or entity of any nature:

 

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(i) engage in or participate within the Market Area in competition with any member of the Company Group in any aspect of the Business, which prohibition shall prevent such Eligible Individual from directly or indirectly: (A) owning, managing, operating, or being an officer or director of, any business that competes with any member of the Company Group in the Market Area, or (B) joining, becoming an employee or consultant of, or otherwise being affiliated with, any person or entity engaged in, or planning to engage in, the Business in the Market Area in competition, or anticipated competition, with any member of the Company Group in any capacity (with respect to this clause) in which such Eligible Individual’s duties or responsibilities are the same as or similar to the duties or responsibilities that such Eligible Individual had on behalf of any member of the Company Group; or

(ii) appropriate any Business Opportunity of, or relating to, any member of the Company Group located in the Market Area.

(f) During the period in which the Eligible Individual is employed by any member of the Company Group and continuing for a period of twelve (12) months following the date that the Eligible Individual is no longer employed by any member of the Company Group, each Eligible Individual shall not, without the prior written approval of the Administrator, directly or indirectly, for such Eligible Individual or on behalf of or in conjunction with any other person or entity of any nature:

(i) solicit, canvass, approach, encourage, entice or induce any customer or supplier (including, for the avoidance of doubt, property owners from whom a member of the Company Group may acquire mineral and royalty interests) of any member of the Company Group with whom or which such Eligible Individual had contact on behalf of any member of the Company Group to cease or lessen such customer’s or supplier’s business with any member of the Company Group; or

(ii) solicit, canvass, approach, encourage, entice or induce any employee or contractor of any member of the Company Group to terminate his, her or its employment or engagement with any member of the Company Group.

(g) Because of the difficulty of measuring economic losses to the Company Group as a result of a breach or threatened breach of the covenants set forth in this Section 9, and because of the immediate and irreparable damage that would be caused to the members of the Company Group for which they would have no other adequate remedy, the Company and each other member of the Company Group shall be entitled to enforce the foregoing covenants, in the event of a breach or threatened breach, by injunctions and restraining orders from any court of competent jurisdiction, without the necessity of showing any actual damages or that money damages would not afford an adequate remedy, and without the necessity of posting any bond or other security. The aforementioned equitable relief shall not be the Company’s or any other member of the Company Group’s exclusive remedy for a breach but instead shall be in addition to all other rights and remedies available to the Company and each other member of the Company Group at law and equity.

 

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(h) The covenants in this Section 9, and each provision and portion hereof, are severable and separate, and the unenforceability of any specific covenant (or portion thereof) shall not affect the provisions of any other covenant (or portion thereof). Moreover, in the event any arbitrator or court of competent jurisdiction shall determine that the scope, time or territorial restrictions set forth are unreasonable, then it is the intention of the parties that such restrictions be enforced to the fullest extent which such arbitrator or court deems reasonable, and this Plan shall thereby be reformed.

10. Administration of this Plan.

(a) Administrator’s Powers and Duties. The Company shall be the named fiduciary and shall have full power to administer this Plan in all of its details, subject to applicable requirements of law. The duties of the Company shall be performed by the Administrator, provided that the Administrator may delegate all or any portion of its duties to an executive officer of the Company. It shall be the duty of the Administrator to see that this Plan is carried out, in accordance with its terms, for the exclusive benefit of persons entitled to participate in this Plan. For this purpose, the Administrator’s powers shall include, but not be limited to, the following authority, in addition to all other powers provided by this Plan:

(i) to make and enforce such rules and regulations as it deems necessary or proper for the efficient administration of this Plan;

(ii) to interpret this Plan and all facts with respect to a claim for payment or benefits. Where such claim is made prior to a Change in Control, the Administrator’s interpretation thereof shall be final and conclusive on all persons claiming payment or benefits under this Plan;

(iii) to decide all questions concerning this Plan and the eligibility of any person to participate in this Plan;

(iv) to make a determination as to the right of any person to a payment or benefit under this Plan (including, without limitation, to determine whether and when there has been a termination of an Eligible Individual’s employment and the cause of such termination and the amount of any payment or benefit due under this Plan);

(v) to appoint such agents, counsel, accountants, consultants, claims administrators and other persons as may be required to assist in administering this Plan;

(vi) to allocate and delegate its responsibilities under this Plan and to designate other persons to carry out any of its responsibilities under this Plan, any such allocation, delegation or designation to be in writing;

(vii) to sue or cause suit to be brought in the name of this Plan; and

(viii) to obtain from the Company and from Eligible Individuals such information as is necessary for the proper administration of this Plan.

 

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(b) Indemnification. The Company shall indemnify and hold harmless the Administrator (and each member thereof) in the performance of its, his or her duties under this Plan against any and all expenses and liabilities arising out of its, his or her administrative functions or fiduciary responsibilities under this Plan, including any expenses and liabilities that are caused by or result from an act or omission constituting the negligence of the Administrator or such member in the performance of such functions or responsibilities, but excluding expenses and liabilities that are caused by or result from such Administrator’s or member’s own gross negligence or willful misconduct. Expenses against which such Administrator or member shall be indemnified hereunder shall include, without limitation, the amounts of any settlement or judgment, costs, counsel fees, and related charges reasonably incurred in connection with a claim asserted or a proceeding brought or settlement thereof.

(c) Compensation, Bond and Expenses. The members of the Administrator shall not receive compensation with respect to their services for the Administrator. To the extent required by applicable law, but not otherwise, Administrator members shall furnish bond or security for the performance of their duties hereunder. Any expenses properly incurred by the Administrator incident to the administration, termination or protection of this Plan, including the cost of furnishing bond, shall be paid by the Company.

(d) Claims Procedure. Any Eligible Individual that the Administrator determines is entitled to a benefit under this Plan is not required to file a claim for benefits. Any Eligible Individual who is not paid a benefit hereunder and who believes that he or she is entitled to a benefit hereunder or who has been paid a benefit and who believes that he or she is entitled to a greater benefit hereunder may file a claim for benefits under this Plan in writing with the Administrator. In any case in which a claim for Plan benefits by an Eligible Individual is denied or modified, the Administrator shall furnish written notice to the claimant within ninety (90) days after receipt of such claim for Plan benefits (or within one hundred eighty (180) days if additional information requested by the Administrator necessitates an extension of the ninety (90)-day period and the claimant is informed of such extension in writing within the original ninety (90)-day period), which notice shall:

(i) state the specific reason or reasons for the denial or modification;

(ii) provide specific reference to pertinent Plan provisions on which the denial or modification is based;

(iii) provide a description of any additional material or information necessary for the Eligible Individual or his or her representative to perfect the claim, and an explanation of why such material or information is necessary; and

(iv) explain this Plan’s claim review procedure as contained herein and describe the Eligible Individual’s right to bring an action under Section 502(a) of ERISA following a denial or modification on review.

 

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In the event a claim for Plan benefits is denied or modified, if the Eligible Individual or his or her representative desires to have such denial or modification reviewed, he or she must, within sixty (60) days following receipt of the notice of such denial or modification, submit a written request for review by the Administrator of its initial decision. In connection with such request, the Eligible Individual or his or her representative may review any pertinent documents upon which such denial or modification was based and may submit issues and comments in writing. Within sixty (60) days following such request for review the Administrator shall, after providing a full and fair review, render its final decision in writing to the Eligible Individual and his or her representative, if any, stating specific reasons for such decision and making specific references to pertinent Plan provisions upon which the decision is based. If special circumstances require an extension of such sixty (60)-day period, the Administrator’s decision shall be rendered as soon as possible, but not later than one hundred twenty (120) days after receipt of the request for review. If an extension of time for review is required, written notice of the extension shall be furnished to the Eligible Individual and his representative, if any, prior to the commencement of the extension period. The Administrator shall be given written notice of its decision on review to the Eligible Individual. In the event a claim for Plan benefits is denied or modified on review, such notice shall set forth the specific reasons for such denial or modification and provide specific references to this Plan provisions on which the denial or modification is based. The notice shall also provide that the Eligible Individual is entitled to receive, upon request and free of charge, reasonable access to, and copies of, all documents, records, and other information relevant to the Eligible Individual’s claim for benefits, including (i) documents, records or other information relied upon for the benefit determination, (ii) documents, records or other information submitted, considered or generated without regard to whether such documents, records or other information were relied upon in making the benefit determination, and (iii) documents, records or other information that demonstrates compliance with the standard claims procedure. The notice shall also contain a statement describing the Eligible Individual’s right to bring an action under Section 502(a) of ERISA. Any legal action with respect to a claim for Plan benefits must be filed no later than one (1) year after the later of (i) the date the claim is denied by the Administrator or (ii) if a review of such denial is requested pursuant to the provisions above, the date of the final decision by the Administrator with respect to such request.

11. General Provisions.

(a) Funding. The benefits provided herein shall he unfunded and shall be provided from the Company’s general assets.

(b) Cost of Plan. The cost of this Plan shall be borne by the Company and no contributions shall be required of the Eligible Individuals.

(c) Plan Year. The Plan shall operate on a calendar year basis.

(d) Amendment and Termination.

(i) The Plan may be amended from time to time or terminated at the discretion of the Board. Notwithstanding anything to the contrary herein, the Administrator, in its sole discretion, may reduce or terminate the coverage of any Eligible Individual under this Plan at any time in its sole and absolute discretion; provided, however, in the event of a Change in Control during the existence of this Plan, this Plan shall remain in full force and effect and benefits may not be reduced during the Change in Control Period.

 

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(ii) The provisions set forth in Section 11(d)(i) that otherwise restrict amendments to this Plan shall not apply to (A) an amendment to the administrative provisions of this Plan that is required pursuant to applicable law, (B) an amendment that increases the benefits payable under this Plan or otherwise constitutes a bona fide improvement of an Eligible Individual’s rights under this Plan or (C) an amendment which decreases the benefits of an Eligible Individual that is consented to in writing by such Eligible Individual.

(e) Not a Contract of Employment. The adoption and maintenance of this Plan shall not be deemed to be a contract of employment between the Company and any person or to be consideration for the employment of any person. Nothing herein contained shall be deemed to give any person the right to be retained in the employ of the Company or to restrict the right of the Company to discharge any person at any time nor shall this Plan be deemed to give the Company the right to require any person to remain in the employ of the Company or to restrict any person’s right to terminate his or her employment at any time.

(f) Severability. Any provision in this Plan that is prohibited or unenforceable in any jurisdiction by reason of applicable law shall, as to such jurisdiction, be ineffective only to the extent of such prohibition or unenforceability without invalidating or affecting the remaining provisions hereof, and any such prohibition or unenforceability in any jurisdiction shall not invalidate or render unenforceable such provision in any other jurisdiction.

(g) After-Acquired Evidence. Notwithstanding any provision of the Plan to the contrary, in the event that the Administrator determines that an Eligible Individual is eligible to receive severance pay or benefits pursuant to Section 4 but, after such determination, the Administrator subsequently acquires evidence or determines that (i) such Eligible Individual has failed to abide by the terms of Section 9 or any other restrictive covenant agreements between such Eligible Individual and any member of the Company Group; or (ii) a Cause condition existed prior to such Eligible Individual’s termination of employment that, had the Company been fully aware of such condition, would have given the Company the right to terminate such Eligible Individual’s employment for Cause, then the Company shall have the right to cease the payment of all pay and benefits pursuant to Section 4, and such Eligible Individual shall promptly return to the Company any payment and any other severance benefits received by such Eligible Individual pursuant to Section 4 prior to the date that the Administrator determines that the conditions of this Section 11(g) have been satisfied.

(h) Nonalienation. Eligible Individual shall not have any right to pledge, hypothecate, anticipate or assign benefits or rights under this Plan, except by will or the laws of descent and distribution.

(i) Effect of Plan. This Plan is intended to supersede all prior oral or written policies of the Company and all prior oral or written communications to Eligible Individual with respect to the subject matter hereof including any employment offer letter with an Eligible Individual, and all such prior policies or communications are hereby null and void and of no further force and effect. Further, this Plan shall be binding upon the Company and any successor of the Company, by merger or otherwise, and shall inure to the benefit of and be enforceable by the Company’s employees.

 

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(j) Taxes. The Company or its successor may withhold from any amounts payable to an Eligible Individual under this Plan such federal, state or local taxes as shall be required to be withheld pursuant to any applicable law or regulation.

(k) Governing Law. All questions arising with respect to the provisions of this Plan and payments due hereunder shall be determined by application of the laws of the Delaware, without giving effect to any conflict of law provisions thereof, except to the extent that Delaware law is preempted by federal law (including by including ERISA, which is the federal law that governs the Plan, the administration of the Plan and any claims made under the Plan). With respect to any claim or dispute related to or arising under this Plan, the Company and each Eligible Individual who signs and returns a Participation Agreement to the Company hereby consent to the exclusive jurisdiction, forum and venue of the state and federal courts located in Denver, Colorado.

(l) Section 409A. The Plan and all benefits provided hereunder are intended to be exempt from Code Section 409A to the maximum extent permitted by applicable law. To the extent that any payment provided hereunder is subject to Code Section 409A, (i) this Plan and all payments provided hereunder are intended to comply with the provisions of Code Section 409A, and (ii) if on the Termination Date the Eligible Individual is a “specified employee,” as defined in Section 409A of the Code, then all or such portion of any severance payments under this Plan that would be subject to the additional tax provided by Section 409A(a)(l)(B) of the Code if not delayed as required by Section 409A(a)(2)(B)(i) of the Code shall be delayed until the date that is six (6) months after the Termination Date (or, if earlier, the Eligible Individual’s date of death) and shall be paid as a lump sum (without interest) on such date.

(m) Notices. For the purposes of this Plan, notices and all other communications shall be in writing and shall be deemed to have been duly given when personally delivered, by facsimile transmission or sent by certified mail, return receipt requested, postage prepaid, or by expedited (overnight) courier with established national reputation, shipping prepaid or billed to sender, in either case addressed to the respective addresses last given by each party to the other (provided that all notices to the Company must be directed to the attention of the General Counsel and Corporate Secretary of the Company) or to such other address as either party may have furnished to the other in writing in accordance herewith. All notices and communication shall be deemed to have been received on the date of delivery thereof, or on the second (2nd) day after deposit thereof with an expedited courier service, except that notice of change of address shall be effective only upon receipt.

(n) Clawback. Any amounts payable under the Plan are subject to any policy (whether in existence as of the Effective Date or later adopted) established by the Company providing for clawback or recovery of amounts that were paid to an Eligible Individual; provided, however, that the establishment or modification of any clawback policy by the Company on or after the date of a Change in Control shall only apply to amounts payable under the Plan to the extent required by applicable law. The Company shall make any determination for clawback or recovery in its sole discretion and in accordance with applicable laws, regulations, and securities exchange listing standards.

 

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Exhibit 10.7

INDEMNIFICATION AGREEMENT

This Indemnification Agreement (“Agreement”) is made as of ______________, 2022 by and between Sitio Royalties Corp. (f/k/a Falcon Minerals Corporation), a Delaware corporation (the “Company”), and _______________ (“Indemnitee”). This Agreement supersedes and replaces any and all previous Agreements between the Company and Indemnitee covering the subject matter of this Agreement.

RECITALS

WHEREAS, highly competent persons have become more reluctant to serve publicly-held corporations as directors or in other capacities unless they are provided with adequate protection through insurance or adequate indemnification against inordinate risks of claims and actions against them arising out of their service to and activities on behalf of the corporation;

WHEREAS, the Board of Directors of the Company (the “Board”) has determined that, in order to attract and retain qualified individuals, the Company will attempt to maintain on an ongoing basis, at its sole expense, liability insurance to protect persons serving the Company and its subsidiaries from certain liabilities. Although the furnishing of such insurance has been a customary and widespread practice among United States-based corporations and other business enterprises, the Company believes that, given current market conditions and trends, such insurance may be available to it in the future only at higher premiums and with more exclusions. At the same time, directors, officers, and other persons in service to corporations or business enterprises are being increasingly subjected to expensive and time-consuming litigation relating to, among other things, matters that traditionally would have been brought only against the Company or business enterprise itself. The Amended and Restated Bylaws of the Company (the “Bylaws”) require indemnification of the officers and directors of the Company. Indemnitee may also be entitled to indemnification pursuant to the General Corporation Law of the State of Delaware (the “DGCL”). The Bylaws and the DGCL expressly provide that the indemnification provisions set forth therein are not exclusive, and thereby contemplate that contracts may be entered into between the Company and members of the board of directors, officers and other persons with respect to indemnification;

WHEREAS, the uncertainties relating to such insurance and to indemnification have increased the difficulty of attracting and retaining such persons;

WHEREAS, the Board has determined that the increased difficulty in attracting and retaining such persons is detrimental to the best interests of the Company and its stockholders and that the Company should act to assure such persons that there will be increased certainty of such protection in the future;

WHEREAS, it is reasonable, prudent and necessary for the Company contractually to obligate itself to indemnify, and to advance expenses on behalf of, such persons to the fullest extent permitted by applicable law so that they will serve or continue to serve the Company free from undue concern that they will not be so indemnified;


WHEREAS, this Agreement is a supplement to and in furtherance of the Bylaws and any resolutions adopted pursuant thereto, and shall not be deemed a substitute therefor, nor to diminish or abrogate any rights of Indemnitee thereunder;

WHEREAS, Indemnitee does not regard the protection available under the Bylaws and insurance as adequate in the present circumstances, and may not be willing to serve as an officer or director without adequate protection, and the Company desires Indemnitee to serve in such capacity. Indemnitee is willing to serve, continue to serve and to take on additional service for or on behalf of the Company on the condition that he be so indemnified; and

NOW, THEREFORE, in consideration of the premises and the covenants contained herein, the Company and Indemnitee do hereby covenant and agree as follows:

Section 1. Services to the Company. Indemnitee agrees to serve as a director and/or an officer of the Company. Indemnitee may at any time and for any reason resign from such position (subject to any other contractual obligation or any obligation imposed by operation of law), in which event the Company shall have no obligation under this Agreement to continue Indemnitee in such position. This Agreement shall not be deemed an employment contract between the Company (or any of its subsidiaries or any Enterprise) and Indemnitee. Indemnitee specifically acknowledges that Indemnitee’s employment with the Company (or any of its subsidiaries or any Enterprise), if any, is at will, and the Indemnitee may be discharged at any time for any reason, with or without cause, except as may be otherwise provided in any written employment contract between Indemnitee and the Company (or any of its subsidiaries or any Enterprise), other applicable formal severance policies duly adopted by the Board, or, with respect to service as a director or officer of the Company, by the Certificate of Incorporation, the Company’s Bylaws, and the DGCL. The foregoing notwithstanding, this Agreement shall continue in force after Indemnitee has ceased to serve as a director of the Company, as provided in Section 16 hereof.

Section 2. Definitions. As used in this Agreement:

(a) References to “agent” shall mean any person who is or was a director, officer, or employee of the Company or a subsidiary of the Company or other person authorized by the Company to act for the Company, to include such person serving in such capacity as a director, officer, employee, fiduciary or other official of another corporation, partnership, limited liability company, joint venture, trust or other enterprise at the request of, for the convenience of, or to represent the interests of the Company or a subsidiary of the Company.

(b) A “Change in Control” shall be deemed to occur upon the earliest to occur after the date of this Agreement of any of the following events:

i. Acquisition of Stock by Third Party. Any Person (as defined below) is or becomes the Beneficial Owner (as defined below), directly or indirectly, of securities of the Company representing forty percent (40%) or more of the combined voting power of the Company’s then outstanding securities unless the change in relative Beneficial Ownership of the Company’s securities by any Person results solely from a reduction in the aggregate number of outstanding shares of securities entitled to vote generally in the election of directors;

 

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ii. Change in Board of Directors. During any period of two (2) consecutive years (not including any period prior to the execution of this Agreement), individuals who at the beginning of such period constitute the Board, and any new director (other than a director designated by a person who has entered into an agreement with the Company to effect a transaction described in Sections 2(b)(i), 2(b)(iii) or 2(b)(iv)) whose election by the Board or nomination for election by the Company’s stockholders was approved by a vote of at least two-thirds of the directors then still in office who either were directors at the beginning of the period or whose election or nomination for election was previously so approved, cease for any reason to constitute at least a majority of the members of the Board;

iii. Corporate Transactions. The effective date of a merger or consolidation of the Company with any other entity, other than a merger or consolidation which would result in the voting securities of the Company outstanding immediately prior to such merger or consolidation continuing to represent (either by remaining outstanding or by being converted into voting securities of the surviving entity) more than 51% of the combined voting power of the voting securities of the surviving entity outstanding immediately after such merger or consolidation and with the power to elect at least a majority of the board of directors or other governing body of such surviving entity;

iv. Liquidation. The approval by the stockholders of the Company of a complete liquidation of the Company or an agreement for the sale or disposition by the Company of all or substantially all of the Company’s assets; and

v. Other Events. There occurs any other event of a nature that would be required to be reported in response to Item 6(e) of Schedule 14A of Regulation 14A (or a response to any similar item on any similar schedule or form) promulgated under the Exchange Act (as defined below), whether or not the Company is then subject to such reporting requirement.

For purposes of this Section 2(b), the following terms shall have the following meanings:

(A) “Exchange Act” shall mean the Securities Exchange Act of 1934, as amended from time to time.

(B) “Person” shall have the meaning as set forth in Sections 13(d) and 14(d) of the Exchange Act; provided, however, that Person shall exclude (i) the Company, (ii) any trustee or other fiduciary holding securities under an employee benefit plan of the Company, and (iii) any corporation owned, directly or indirectly, by the stockholders of the Company in substantially the same proportions as their ownership of stock of the Company.

(C) “Beneficial Owner” shall have the meaning given to such term in Rule 13d-3 under the Exchange Act; provided, however, that Beneficial Owner shall exclude any Person otherwise becoming a Beneficial Owner by reason of the stockholders of the Company approving a merger of the Company with another entity.

 

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(c) “Corporate Status” describes the status of a person who is or was a director, trustee, partner, managing member, manager, fiduciary, officer, employee or agent of the Company or of any other corporation, limited liability company, partnership or joint venture, trust or other enterprise which such person is or was serving at the request of the Company.

(d) “Disinterested Director” shall mean a director of the Company who is not and was not a party to the Proceeding in respect of which indemnification is sought by Indemnitee.

(e) “Enterprise” shall mean the Company and any other corporation, limited liability company, partnership, joint venture, trust or other enterprise of which Indemnitee is or was serving at the request of the Company as a director, officer, trustee, partner, managing member, manager, employee, agent or fiduciary.

(f) “Expenses” shall include all reasonable attorneys’ fees, retainers, court costs, transcript costs, fees of experts and other professionals, witness fees, travel expenses, duplicating costs, printing and binding costs, telephone charges, postage, delivery service fees, any federal, state, local or foreign taxes imposed on Indemnitee as a result of the actual or deemed receipt of any payments under this Agreement, ERISA excise taxes and penalties, and all other disbursements or expenses of the types customarily incurred in connection with, or as a result of, prosecuting, defending, preparing to prosecute or defend, investigating, being or preparing to be a deponent or witness in, or otherwise participating in, a Proceeding. Expenses also shall include (i) Expenses incurred in connection with any appeal resulting from any Proceeding, including without limitation the premium, security for, and other costs relating to any cost bond, supersedeas bond, or other appeal bond or its equivalent, (ii) expenses incurred in connection with recovery under any directors’ and officers’ liability insurance policies maintained by the Company, and (iii) for purposes of Section 14(d) only, Expenses incurred by or on behalf of Indemnitee in connection with the interpretation, enforcement or defense of Indemnitee’s rights under this Agreement, the Certificate of Incorporation, the Bylaws or under any directors’ and officers’ liability insurance policies maintained by the Company, by litigation or otherwise. The parties agree that for the purposes of any advancement of Expenses for which Indemnitee has made written demand to the Company in accordance with this Agreement, all Expenses included in such demand that are certified by affidavit of Indemnitee’s counsel as being reasonable shall be presumed conclusively to be reasonable. Expenses, however, shall not include amounts paid in settlement by Indemnitee or the amount of judgments or fines against Indemnitee.

(g) “Independent Counsel” shall mean a law firm, or a member of a law firm, that is experienced in matters of corporation law and neither presently is, nor in the past five years has been, retained to represent: (i) the Company or Indemnitee in any matter material to either such party (other than with respect to matters concerning the Indemnitee under this Agreement, or of other indemnitees under similar indemnification agreements), or (ii) any other party to the Proceeding giving rise to a claim for indemnification hereunder. Notwithstanding the foregoing, the term “Independent Counsel” shall not include any person who, under the applicable standards of professional conduct then prevailing, would have a conflict of interest in representing either the Company or Indemnitee in an action to determine Indemnitee’s rights under this Agreement. The Company agrees to pay the reasonable fees and expenses of the Independent Counsel referred to above and to fully indemnify such counsel against any and all Expenses, claims, liabilities and damages arising out of or relating to this Agreement or its engagement pursuant hereto.

 

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(h) The term “Proceeding” shall include any threatened, pending or completed action, suit, claim, counterclaim, cross claim, arbitration, mediation, alternate dispute resolution mechanism, investigation, inquiry, administrative hearing or any other actual, threatened or completed proceeding, whether brought in the right of the Company or otherwise and whether of a civil, criminal, administrative, legislative, regulatory or investigative (formal or informal) nature, including any appeal therefrom, in which Indemnitee was, is or will be involved as a party, potential party, non-party witness or otherwise by reason of the Indemnitee’s Corporate Status, by reason of any action taken by him (or a failure to take action by him) or of any action (or failure to act) on his part while acting pursuant to his Corporate Status, in each case whether or not serving in such capacity at the time any liability or Expense is incurred for which indemnification, reimbursement, or advancement of Expenses can be provided under this Agreement. If the Indemnitee believes in good faith that a given situation may lead to or culminate in the institution of a Proceeding, this shall be considered a Proceeding under this paragraph.

(i) Reference to “other enterprise” shall include employee benefit plans; references to “fines” shall include any excise tax assessed with respect to any employee benefit plan; references to “serving at the request of the Company” shall include any service as a director, officer, employee or agent of the Company which imposes duties on, or involves services by, such director, officer, employee or agent with respect to an employee benefit plan, its participants or beneficiaries; and a person who acted in good faith and in a manner he reasonably believed to be in the best interests of the participants and beneficiaries of an employee benefit plan shall be deemed to have acted in manner “not opposed to the best interests of the Company” as referred to in this Agreement.

Section 3. Indemnity in Third-Party Proceedings. The Company shall indemnify Indemnitee in accordance with the provisions of this Section 3 if Indemnitee is, or is threatened to be made, a party to or a participant in any Proceeding, other than a Proceeding by or in the right of the Company to procure a judgment in its favor. Pursuant to this Section 3, Indemnitee shall be indemnified to the fullest extent permitted by applicable law against all Expenses, judgments, fines, penalties, amounts paid in settlement and other liability and loss suffered (including all interest, assessments and other charges paid or payable in connection with or in respect of such Expenses, judgments, fines, penalties, amounts paid in settlement and other liability and loss suffered) actually and reasonably incurred by Indemnitee or on his behalf in connection with such Proceeding or any claim, issue or matter therein, if Indemnitee acted in good faith and in a manner he reasonably believed to be in or not opposed to the best interests of the Company and, in the case of a criminal Proceeding had no reasonable cause to believe that his conduct was unlawful. The parties hereto intend that this Agreement shall provide to the fullest extent permitted by law for indemnification in excess of that expressly permitted by statute, including, without limitation, any indemnification provided by the Certificate of Incorporation, the Bylaws, vote of its stockholders or disinterested directors or applicable law.

Section 4. Indemnity in Proceedings by or in the Right of the Company. The Company shall indemnify Indemnitee in accordance with the provisions of this Section 4 if Indemnitee is, or is threatened to be made, a party to or a participant in any Proceeding by or in the right of the Company to procure a judgment in its favor. Pursuant to this Section 4, Indemnitee shall be indemnified to the fullest extent permitted by applicable law against all Expenses, judgments, fines, penalties, amounts paid in settlement and other liability and loss (including all

 

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interest, assessments and other charges paid or payable in connection with or in respect of such Expenses, judgments, fines, penalties, amounts paid in settlement and other liability and loss suffered) actually and reasonably incurred by him or on his behalf in connection with such Proceeding or any claim, issue or matter therein, if Indemnitee acted in good faith and in a manner he reasonably believed to be in or not opposed to the best interests of the Company. No indemnification for Expenses, judgments, fines, penalties, amounts paid in settlement and other liability and loss (including all interest, assessments and other charges paid or payable in connection with or in respect of such Expenses, judgments, fines, penalties, amounts paid in settlement and other liability and loss suffered) shall be made under this Section 4 in respect of any claim, issue or matter as to which Indemnitee shall have been finally adjudged by a court of competent jurisdiction (after the time for an appeal has expired) to be liable to the Company, unless and only to the extent that the Delaware Court of Chancery or any court in which the Proceeding was brought shall determine upon application that, despite the adjudication of liability but in view of all the circumstances of the case, Indemnitee is fairly and reasonably entitled to indemnification.

Section 5. Indemnification for Expenses of a Party Who is Wholly or Partly Successful. Notwithstanding any other provisions of this Agreement, to the fullest extent permitted by applicable law and to the extent that Indemnitee is a party to (or a participant in) and is successful, on the merits or otherwise, in any Proceeding or in defense of any claim, issue or matter therein, in whole or in part, the Company shall indemnify Indemnitee against all Expenses actually and reasonably incurred by him in connection therewith. If Indemnitee is not wholly successful in such Proceeding but is successful, on the merits or otherwise, as to one or more but less than all claims, issues or matters in such Proceeding, the Company shall indemnify Indemnitee against all Expenses actually and reasonably incurred by him or on his behalf in connection with or related to each successfully resolved claim, issue or matter to the fullest extent permitted by law. For purposes of this Section and without limitation, the termination of any claim, issue or matter in such a Proceeding by dismissal, with or without prejudice, shall be deemed to be a successful result as to such claim, issue or matter.

Section 6. Indemnification For Expenses of a Witness. Notwithstanding any other provision of this Agreement, to the fullest extent permitted by applicable law and to the extent that Indemnitee is, by reason of his Corporate Status, a witness, is required to respond to discovery requests in any Proceeding or otherwise asked to participate in any Proceeding to which Indemnitee is not a party, he shall be indemnified against all Expenses actually and reasonably incurred by him or on his behalf in connection therewith.

Section 7. Partial Indemnification. If Indemnitee is entitled under any provision of this Agreement to indemnification by the Company for some or a portion of Expenses, but not, however, for the total amount thereof, the Company shall nevertheless indemnify Indemnitee for the portion thereof to which Indemnitee is entitled.

Section 8. Additional Indemnification.

(a) Notwithstanding any limitation in Sections 3, 4, or 5, the Company shall indemnify Indemnitee to the fullest extent permitted by applicable law if Indemnitee, by reason of his Corporate Status, is a party to or threatened to be made a party to any Proceeding (including a Proceeding by or in the right of the Company to procure a judgment in its favor) against all

 

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Expenses, judgments, fines, penalties, amounts paid in settlement and other liability and loss suffered (including all interest, assessments and other charges paid or payable in connection with or in respect of such Expenses, judgments, fines, penalties, amounts paid in settlement and other liability and loss suffered) actually and reasonably incurred by Indemnitee in connection with the Proceeding.

(b) For purposes of Section 8(a), the meaning of the phrase “to the fullest extent permitted by applicable law” shall include, but not be limited to:

i. to the fullest extent permitted by the provision of the DGCL that authorizes or contemplates additional indemnification by agreement, or the corresponding provision of any amendment to or replacement of the DGCL, and

ii. to the fullest extent authorized or permitted by any amendments to or replacements of the DGCL adopted after the date of this Agreement that increase the extent to which a corporation may indemnify its officers and directors.

Section 9. Exclusions. Notwithstanding any provision in this Agreement, the Company shall not be obligated under this Agreement to make any indemnification payment in connection with any claim made against Indemnitee:

(a) for which payment has actually been made to or on behalf of Indemnitee under any insurance policy or other indemnity provision, except with respect to any excess beyond the amount paid under any insurance policy or other indemnity provision; or

(b) for (i) an accounting of profits made from the purchase and sale (or sale and purchase) by Indemnitee of securities of the Company within the meaning of Section 16(b) of the Exchange Act (as defined in Section 2(b) hereof) or similar provisions of state statutory law or common law, or (ii) any reimbursement of the Company by the Indemnitee of any bonus or other incentive-based or equity-based compensation or of any profits realized by the Indemnitee from the sale of securities of the Company, as required in each case under the Exchange Act (including any such reimbursements that arise from an accounting restatement of the Company pursuant to Section 304 of the Sarbanes-Oxley Act of 2002 (the “Sarbanes-Oxley Act”), or the payment to the Company of profits arising from the purchase and sale by Indemnitee of securities in violation of Section 306 of the Sarbanes-Oxley Act), or (iii) any reimbursement of the Company by Indemnitee of any compensation pursuant to any compensation recoupment or clawback policy adopted by the Board or the compensation committee of the Board, including but not limited to any such policy adopted to comply with stock exchange listing requirements implementing Section 10D of the Exchange Act; or

(c) except as provided in Section 14(d) of this Agreement, in connection with any Proceeding (or any part of any Proceeding) initiated by Indemnitee, including any Proceeding (or any part of any Proceeding) initiated by Indemnitee against the Company or its directors, officers, employees or other indemnitees, unless (i) the Board authorized the Proceeding (or any part of any Proceeding) prior to its initiation, (ii) such payment arises in connection with any mandatory counterclaim or cross-claim or affirmative defense brought or raised by Indemnitee in any Proceeding (or any part of any Proceeding), or (iii) the Company provides the indemnification, in its sole discretion, pursuant to the powers vested in the Company under applicable law.

 

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Section 10. Advances of Expenses. Notwithstanding any provision of this Agreement to the contrary (other than Section 14(d)), the Company shall advance, to the extent not prohibited by law, the Expenses incurred by Indemnitee in connection with any Proceeding (or any part of any Proceeding) not initiated by Indemnitee, and such advancement shall be made within thirty (30) days after the receipt by the Company of a statement or statements requesting such advances from time to time, whether prior to or after final disposition of any Proceeding. Advances shall be unsecured and interest free. Advances shall be made without regard to Indemnitee’s ability to repay the Expenses and without regard to Indemnitee’s ultimate entitlement to indemnification under the other provisions of this Agreement. In accordance with Section 14(d), advances shall include any and all reasonable Expenses incurred pursuing an action to enforce this right of advancement, including Expenses incurred preparing and forwarding statements to the Company to support the advances claimed. The Indemnitee shall qualify for advances upon the execution and delivery to the Company of this Agreement, which shall constitute an undertaking providing that the Indemnitee undertakes to repay the amounts advanced (without interest) to the extent that it is ultimately determined that Indemnitee is not entitled to be indemnified by the Company. No other form of undertaking shall be required other than the execution of this Agreement. This Section 10 shall not apply to any claim made by Indemnitee for which indemnity is excluded pursuant to Section 9.

Section 11. Procedure for Notification and Defense of Claim.

(a) Indemnitee shall notify the Company in writing of any matter with respect to which Indemnitee intends to seek indemnification or advancement of Expenses hereunder as soon as reasonably practicable following the receipt by Indemnitee of written notice thereof. The written notification to the Company shall include a description of the nature of the Proceeding and the facts underlying the Proceeding, in each case, to the extent known to Indemnitee. To obtain indemnification under this Agreement, Indemnitee shall submit to the Company a written request, including therein or therewith such documentation and information as is reasonably available to Indemnitee and is reasonably necessary to determine whether and to what extent Indemnitee is entitled to indemnification following the final disposition of such Proceeding. The omission by Indemnitee to notify the Company hereunder will not relieve the Company from any liability which it may have to Indemnitee hereunder or otherwise than under this Agreement, and any delay in so notifying the Company shall not constitute a waiver by Indemnitee of any rights under this Agreement. The Secretary of the Company shall, promptly upon receipt of such a request for indemnification, advise the Board in writing that Indemnitee has requested indemnification.

(b) The Company will be entitled to participate in the Proceeding at its own expense.

 

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Section 12. Procedure Upon Application for Indemnification.

(a) Upon written request by Indemnitee for indemnification pursuant to Section 11(a), a determination, if required by applicable law, with respect to Indemnitee’s entitlement thereto shall be made in the specific case: (i) if a Change in Control shall have occurred, by Independent Counsel in a written opinion to the Board, a copy of which shall be delivered to Indemnitee; or (ii) if a Change in Control shall not have occurred, (A) if requested by Indemnitee, by Independent Counsel, a copy of which shall be delivered to Indemnitee, (B) by a majority vote of the Disinterested Directors, even though less than a quorum of the Board, (C) by a committee of Disinterested Directors designated by a majority vote of the Disinterested Directors, even though less than a quorum of the Board, (D) if there are no such Disinterested Directors or, if such Disinterested Directors so direct, by Independent Counsel in a written opinion to the Board, a copy of which shall be delivered to Indemnitee or (E) if so directed by the Board, by the stockholders of the Company; and, if it is so determined that Indemnitee is entitled to indemnification, payment to Indemnitee shall be made within ten (10) days after such determination. Indemnitee shall cooperate with the person, persons or entity making such determination with respect to Indemnitee’s entitlement to indemnification, including providing to such person, persons or entity upon reasonable advance request any documentation or information which is not privileged or otherwise protected from disclosure and which is reasonably available to Indemnitee and reasonably necessary to such determination. Any costs or Expenses (including attorneys’ fees and disbursements) incurred by Indemnitee in so cooperating with the person, persons or entity making such determination shall be borne by the Company (irrespective of the determination as to Indemnitee’s entitlement to indemnification) and the Company hereby indemnifies and agrees to hold Indemnitee harmless therefrom. The Company promptly will advise Indemnitee in writing with respect to any determination that Indemnitee is or is not entitled to indemnification, including a description of any reason or basis for which indemnification has been denied.

(b) In the event the determination of entitlement to indemnification is to be made by Independent Counsel pursuant to Section 12(a) hereof, the Independent Counsel shall be selected as provided in this Section 12(b). If a Change in Control shall not have occurred, the Independent Counsel shall be selected by the Board, and the Company shall give written notice to Indemnitee advising him of the identity of the Independent Counsel so selected. If a Change in Control shall have occurred, the Independent Counsel shall be selected by Indemnitee (unless Indemnitee shall request that such selection be made by the Board, in which event the preceding sentence shall apply), and Indemnitee shall give written notice to the Company advising it of the identity of the Independent Counsel so selected. In either event, Indemnitee or the Company, as the case may be, may, within ten (10) days after such written notice of selection shall have been given, deliver to the Company or to Indemnitee, as the case may be, a written objection to such selection; provided, however, that such objection may be asserted only on the ground that the Independent Counsel so selected does not meet the requirements of “Independent Counsel” as defined in Section 2 of this Agreement, and the objection shall set forth with particularity the factual basis of such assertion. Absent a proper and timely objection, the person so selected shall act as Independent Counsel. If such written objection is so made and substantiated, the Independent Counsel so selected may not serve as Independent Counsel unless and until such objection is withdrawn or the Delaware Court has determined that such objection is without merit. If, within twenty (20) days after the later of submission by Indemnitee of a written request for indemnification pursuant to Section 11(a) hereof and the final disposition of the Proceeding, no Independent Counsel shall have been selected and not objected to, either the Company or Indemnitee may petition the Delaware Court for resolution of any objection which shall have been made by the Company or Indemnitee to the other’s selection of Independent Counsel and/or for the appointment as Independent Counsel of a person selected by such court or by such other person as such court shall designate, and the person with respect to whom all objections are so resolved

 

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or the person so appointed shall act as Independent Counsel under Section 12(a) hereof. Upon the due commencement of any judicial proceeding or arbitration pursuant to Section 14(a) of this Agreement, Independent Counsel shall be discharged and relieved of any further responsibility in such capacity (subject to the applicable standards of professional conduct then prevailing).

Section 13. Presumptions and Effect of Certain Proceedings.

(a) In making a determination with respect to entitlement to indemnification hereunder, the person or persons or entity making such determination shall, to the fullest extent not prohibited by law, presume that Indemnitee is entitled to indemnification under this Agreement if Indemnitee has submitted a request for indemnification in accordance with Section 11(a) of this Agreement, and the Company shall, to the fullest extent not prohibited by law, have the burden of proof to overcome that presumption in connection with the making by any person, persons or entity of any determination contrary to that presumption. Neither the failure of the Company (including by its directors or Independent Counsel) to have made a determination prior to the commencement of any action pursuant to this Agreement that indemnification is proper in the circumstances because Indemnitee has met the applicable standard of conduct, nor an actual determination by the Company (including by its directors or Independent Counsel) that Indemnitee has not met such applicable standard of conduct, shall be a defense to the action or create a presumption that Indemnitee has not met the applicable standard of conduct.

(b) Subject to Section 14(e), if the person, persons or entity empowered or selected under Section 12 of this Agreement to determine whether Indemnitee is entitled to indemnification shall not have made a determination within sixty (60) days after receipt by the Company of the request therefor, the requisite determination of entitlement to indemnification shall, to the fullest extent not prohibited by law, be deemed to have been made and Indemnitee shall be entitled to such indemnification, absent (i) a misstatement by Indemnitee of a material fact, or an omission of a material fact necessary to make Indemnitee’s statement not materially misleading, in connection with the request for indemnification, or (ii) a prohibition of such indemnification under applicable law; provided, however, that such 60-day period may be extended for a reasonable time, not to exceed an additional thirty (30) days, if the person, persons or entity making the determination with respect to entitlement to indemnification in good faith requires such additional time for the obtaining or evaluating of documentation and/or information relating thereto; and provided, further, that the foregoing provisions of this Section 13(b) shall not apply (i) if the determination of entitlement to indemnification is to be made by the stockholders pursuant to Section 12(a) of this Agreement and if (A) within fifteen (15) days after receipt by the Company of the request for such determination the Board has resolved to submit such determination to the stockholders for their consideration at an annual meeting thereof to be held within seventy-five (75) days after such receipt and such determination is made thereat, or (B) a special meeting of stockholders is called within fifteen (15) days after such receipt for the purpose of making such determination, such meeting is held for such purpose within sixty (60) days after having been so called and such determination is made thereat, or (ii) if the determination of entitlement to indemnification is to be made by Independent Counsel pursuant to Section 12(a) of this Agreement.

 

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(c) The termination of any Proceeding or of any claim, issue or matter therein, by judgment, order, settlement or conviction, or upon a plea of nolo contendere or its equivalent, shall not (except as otherwise expressly provided in this Agreement) of itself adversely affect the right of Indemnitee to indemnification or create a presumption that Indemnitee did not act in good faith and in a manner which he reasonably believed to be in or not opposed to the best interests of the Company or, with respect to any criminal Proceeding, that Indemnitee had reasonable cause to believe that his conduct was unlawful.

(d) For purposes of any determination of good faith, Indemnitee shall be deemed to have acted in good faith if Indemnitee’s action is based on the records or books of account of the Enterprise, including financial statements, or on information supplied to Indemnitee by the directors or officers of the Enterprise in the course of their duties, or on the advice of legal counsel for the Enterprise or on information or records given or reports made to the Enterprise by an independent certified public accountant or by an appraiser or other expert selected with the reasonable care by the Enterprise. The provisions of this Section 13(d) shall not be deemed to be exclusive or to limit in any way the other circumstances in which the Indemnitee may be deemed to have met the applicable standard of conduct set forth in this Agreement.

(e) The knowledge and/or actions, or failure to act, of any director, officer, trustee, partner, managing member, fiduciary, agent or employee of the Enterprise shall not be imputed to Indemnitee for purposes of determining the right to indemnification under this Agreement.

Section 14. Remedies of Indemnitee.

(a) Subject to Section 14(e), in the event that (i) a determination is made pursuant to Section 12 of this Agreement that Indemnitee is not entitled to indemnification under this Agreement, (ii) advancement of Expenses is not timely made pursuant to Section 10 of this Agreement, (iii) no determination of entitlement to indemnification shall have been made pursuant to Section 12(a) of this Agreement within ninety (90) days after receipt by the Company of the request for indemnification, (iv) payment of indemnification is not made pursuant to Section 5, 6 or 7 or the last sentence of Section 12(a) of this Agreement within ten (10) days after receipt by the Company of a written request therefor, (v) payment of indemnification pursuant to Section 3, 4 or 8 of this Agreement is not made within ten (10) days after a determination has been made that Indemnitee is entitled to indemnification, or (vi) in the event that the Company or any other person takes or threatens to take any action to declare this Agreement void or unenforceable, or institutes any litigation or other action or Proceeding designed to deny, or to recover from, the Indemnitee the benefits provided or intended to be provided to the Indemnitee hereunder, Indemnitee shall be entitled to an adjudication by a court of his entitlement to such indemnification or advancement of Expenses. Alternatively, Indemnitee, at his option, may seek an award in arbitration to be conducted by a single arbitrator pursuant to the Commercial Arbitration Rules of the American Arbitration Association. Indemnitee shall commence such proceeding seeking an adjudication or an award in arbitration within 180 days following the date on which Indemnitee first has the right to commence such proceeding pursuant to this Section 14(a); provided, however, that the foregoing clause shall not apply in respect of a proceeding brought by Indemnitee to enforce his rights under Section 5 of this Agreement. The Company shall not oppose Indemnitee’s right to seek any such adjudication or award in arbitration.

 

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(b) In the event that a determination shall have been made pursuant to Section 12(a) of this Agreement that Indemnitee is not entitled to indemnification, any judicial proceeding or arbitration commenced pursuant to this Section 14 shall be conducted in all respects as a de novo trial, or arbitration, on the merits and Indemnitee shall not be prejudiced by reason of that adverse determination. In any judicial proceeding or arbitration commenced pursuant to this Section 14 the Company shall have the burden of proving Indemnitee is not entitled to indemnification or advancement of Expenses, as the case may be.

(c) If a determination shall have been made pursuant to Section 12(a) of this Agreement that Indemnitee is entitled to indemnification, the Company shall be bound by such determination in any judicial proceeding or arbitration commenced pursuant to this Section 14, absent (i) a misstatement by Indemnitee of a material fact, or an omission of a material fact necessary to make Indemnitee’s statement not materially misleading, in connection with the request for indemnification, or (ii) a prohibition of such indemnification under applicable law.

(d) The Company shall, to the fullest extent not prohibited by law, be precluded from asserting in any judicial proceeding or arbitration commenced pursuant to this Section 14 that the procedures and presumptions of this Agreement are not valid, binding and enforceable and shall stipulate in any such court or before any such arbitrator that the Company is bound by all the provisions of this Agreement. It is the intent of the Company that, to the fullest extent permitted by law, the Indemnitee not be required to incur legal fees or other Expenses associated with the interpretation, enforcement or defense of Indemnitee’s rights under this Agreement by litigation or otherwise because the cost and expense thereof would substantially detract from the benefits intended to be extended to the Indemnitee hereunder. The Company shall, to the fullest extent permitted by law, indemnify Indemnitee against any and all Expenses and, if requested by Indemnitee, shall (within ten (10) days after receipt by the Company of a written request therefor) advance, to the extent not prohibited by law, such Expenses to Indemnitee, which are incurred by Indemnitee in connection with any action brought by Indemnitee for indemnification or advance of Expenses from the Company under this Agreement or under any directors’ and officers’ liability insurance policies maintained by the Company if, in the case of indemnification, Indemnitee is wholly successful on the underlying claims; if Indemnitee is not wholly successful on the underlying claims, then such indemnification shall be only to the extent Indemnitee is successful on such underlying claims or otherwise as permitted by law, whichever is greater.

(e) Notwithstanding anything in this Agreement to the contrary, no determination as to entitlement of Indemnitee to indemnification under this Agreement shall be required to be made prior to the final disposition of the Proceeding.

Section 15. Non-exclusivity; Survival of Rights; Insurance; Subrogation.

(a) The rights of indemnification and to receive advancement of Expenses as provided by this Agreement shall not be deemed exclusive of any other rights to which Indemnitee may at any time be entitled under applicable law, the Certificate of Incorporation, the Bylaws, any agreement, a vote of stockholders or a resolution of directors, or otherwise. No amendment, alteration or repeal of this Agreement or of any provision hereof shall limit or restrict any right of Indemnitee under this Agreement in respect of any action taken or omitted by such Indemnitee in his Corporate Status prior to such amendment, alteration or repeal. To the extent that a change in

 

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Delaware law, whether by statute or judicial decision, permits greater indemnification or advancement of Expenses than would be afforded currently under the Bylaws and this Agreement, it is the intent of the parties hereto that Indemnitee shall enjoy by this Agreement the greater benefits so afforded by such change. No right or remedy herein conferred is intended to be exclusive of any other right or remedy, and every other right and remedy shall be cumulative and in addition to every other right and remedy given hereunder or now or hereafter existing at law or in equity or otherwise. The assertion or employment of any right or remedy hereunder, or otherwise, shall not prevent the concurrent assertion or employment of any other right or remedy.

(b) To the extent that the Company maintains an insurance policy or policies providing liability insurance for directors, officers, employees, or agents of the Enterprise, Indemnitee shall be covered by such policy or policies in accordance with its or their terms to the maximum extent of the coverage available for any such director, officer, employee or agent under such policy or policies. If, at the time of the receipt of a notice of a claim pursuant to the terms hereof, the Company has director and officer liability insurance in effect, the Company shall give prompt notice of such claim or of the commencement of a Proceeding, as the case may be, to the insurers in accordance with the procedures set forth in the respective policies. The Company shall thereafter take all necessary or desirable action to cause such insurers to pay, on behalf of the Indemnitee, all amounts payable as a result of such Proceeding in accordance with the terms of such policies.

(c) In the event of any payment under this Agreement, the Company shall be subrogated to the extent of such payment to all of the rights of recovery of Indemnitee, who shall execute all papers required and take all action necessary to secure such rights, including execution of such documents as are necessary to enable the Company to bring suit to enforce such rights.

(d) The Company shall not be liable under this Agreement to make any payment of amounts otherwise indemnifiable (or for which advancement is provided hereunder) hereunder if and to the extent that Indemnitee has otherwise actually received such payment under any insurance policy, contract, agreement or otherwise.

(e) The Company’s obligation to indemnify or advance Expenses hereunder to Indemnitee who is or was serving at the request of the Company as a director, officer, trustee, partner, managing member, fiduciary, employee or agent of any other corporation, limited liability company, partnership, joint venture, trust, employee benefit plan or other enterprise shall be reduced by any amount Indemnitee has actually received as indemnification or advancement of Expenses from such other corporation, limited liability company, partnership, joint venture, trust or other enterprise.

(f) The Company hereby acknowledges that Indemnitee may have certain rights to indemnification, advancement and insurance provided by one or more Persons with whom or which Indemnitee may be associated. The Company hereby acknowledges and agrees that (i) the Company shall be the indemnitor of first resort with respect to any Proceeding, Expense, liability or matter that is the subject of the Indemnity Obligations (as defined below), (ii) the Company shall be primarily liable for all Indemnity Obligations and any indemnification afforded to Indemnitee in respect of any Proceeding, Expense, liability or matter that is the subject of Indemnity Obligations, whether created by applicable law, organizational or constituent

 

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documents, contract (including this Agreement) or otherwise, (iii) any obligation of any other Persons with whom or which Indemnitee may be associated to indemnify Indemnitee or advance Expenses or liabilities to Indemnitee in respect of any Proceeding shall be secondary to the obligations of the Company hereunder, (iv) the Company shall be required to indemnify Indemnitee and advance Expenses or liabilities to Indemnitee hereunder to the fullest extent provided herein without regard to any rights Indemnitee may have against any other Person with whom or which Indemnitee may be associated or insurer of any such Person and (v) the Company irrevocably waives, relinquishes and releases any other Person with whom or which Indemnitee may be associated from any claim of contribution, subrogation or any other recovery of any kind in respect of amounts paid by the Company hereunder. In the event any other Person with whom or which Indemnitee may be associated or their insurers advances or extinguishes any liability or loss which is the subject of any Indemnity Obligation owed by the Company or payable under any Company insurance policy, the payor shall have a right of subrogation against the Company or its insurer or insurers for all amounts so paid which would otherwise be payable by the Company or its insurer or insurers under this Agreement. In no event will payment of an Indemnity Obligation by any other Person with whom or which Indemnitee may be associated or their insurers affect the obligations of the Company hereunder or shift primary liability for any Indemnity Obligation to any other Person with whom or which Indemnitee may be associated. Any indemnification, insurance or advancement provided by any other Person with whom or which Indemnitee may be associated with respect to any liability arising as a result of Indemnitee’s status as director, officer, employee or agent of the Company or capacity as an officer or director of any Person is specifically in excess over any Indemnity Obligation of the Company or valid and any collectible insurance (including but not limited to any malpractice insurance or professional errors and omissions insurance) provided by the Company under this Agreement. As used herein, the term “Indemnity Obligations” shall mean all obligations of the Company to Indemnitee under the Certificate of Incorporation, the Bylaws, this Agreement or otherwise, including the Company’s obligations to provide indemnification to Indemnitee and advance Expenses to Indemnitee under this Agreement.

Section 16. Duration of Agreement. This Agreement shall continue for so long as Indemnitee serves as a director, officer, employee, agent or fiduciary of the Company or, at the request of the Company, as a director, officer, partner, member, venturer, proprietor, trustee, employee, agent, fiduciary or similar functionary of another foreign or domestic corporation, partnership, limited liability company, joint venture, sole proprietorship, trust, employee benefit plan or other enterprise, and shall continue thereafter so long as Indemnitee shall be subject to any possible Proceeding (including any rights of appeal thereto and any Proceeding commenced by Indemnitee pursuant to Section 14 of this Agreement) by reason of Indemnitee’s Corporate Status, whether or not Indemnitee is acting in any such capacity at the time any liability or expense is incurred for which indemnification or advancement can be provided under this Agreement. The indemnification and advancement of expenses rights provided by or granted pursuant to this Agreement shall be binding upon and be enforceable by the parties hereto and their respective successors and assigns (including any direct or indirect successor by purchase, merger, consolidation or otherwise to all or substantially all of the business or assets of the Company), shall continue as to an Indemnitee who has ceased to be a director, officer, employee or agent of the Company or of any other Enterprise, and shall inure to the benefit of Indemnitee and his or her spouse, assigns, heirs, devisees, executors and administrators and other legal representatives.

 

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Section 17. Severability. If any provision or provisions of this Agreement shall be held to be invalid, illegal or unenforceable for any reason whatsoever: (a) the validity, legality and enforceability of the remaining provisions of this Agreement (including without limitation, each portion of any Section of this Agreement containing any such provision held to be invalid, illegal or unenforceable, that is not itself invalid, illegal or unenforceable) shall not in any way be affected or impaired thereby and shall remain enforceable to the fullest extent permitted by law; (b) such provision or provisions shall be deemed reformed to the extent necessary to conform to applicable law and to give the maximum effect to the intent of the parties hereto; and (c) to the fullest extent possible, the provisions of this Agreement (including, without limitation, each portion of any Section of this Agreement containing any such provision held to be invalid, illegal or unenforceable, that is not itself invalid, illegal or unenforceable) shall be construed so as to give effect to the intent manifested thereby.

Section 18. Enforcement.

(a) The Company expressly confirms and agrees that it has entered into this Agreement and assumed the obligations imposed on it hereby in order to induce Indemnitee to serve as a director or officer of the Company, and the Company acknowledges that Indemnitee is relying upon this Agreement in serving as a director or officer of the Company.

(b) This Agreement constitutes the entire agreement between the parties hereto with respect to the subject matter hereof and supersedes all prior agreements and understandings, oral, written and implied, between the parties hereto with respect to the subject matter hereof; provided, however, that this Agreement is a supplement to and in furtherance of the Certificate of Incorporation, the Bylaws and applicable law, and shall not be deemed a substitute therefor, nor to diminish or abrogate any rights of Indemnitee thereunder.

Section 19. Modification and Waiver. No supplement, modification or amendment of this Agreement shall be binding unless executed in writing by the parties hereto. No waiver of any of the provisions of this Agreement shall be deemed or shall constitute a waiver of any other provisions of this Agreement nor shall any waiver constitute a continuing waiver.

Section 20. Notice by Indemnitee. Indemnitee agrees promptly to notify the Company in writing upon being served with any summons, citation, subpoena, complaint, indictment, information or other document relating to any Proceeding or matter which may be subject to indemnification or advancement of Expenses covered hereunder. The failure of Indemnitee to so notify the Company shall not relieve the Company of any obligation which it may have to the Indemnitee under this Agreement or otherwise.

Section 21. Notices. All notices, requests, demands and other communications under this Agreement shall be in writing and shall be deemed to have been duly given if (a) delivered by hand and receipted for by the party to whom said notice or other communication shall have been directed, (b) mailed by certified or registered mail with postage prepaid, on the third business day after the date on which it is so mailed, (c) mailed by reputable overnight courier and receipted for by the party to whom said notice or other communication shall have been directed, (d) sent by facsimile transmission, with receipt of oral confirmation that such transmission has been received, or (e) sent by e-mail, with receipt of written confirmation by e-mail that such transmission has been received:

(a) If to Indemnitee, at the address indicated on the signature page of this Agreement, or such other address as Indemnitee shall provide to the Company.

 

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(b) If to the Company to

Sitio Royalties Corp.

1401 Lawrence St, Suite 1750

Denver, Colorado 80202

Attention: General Counsel

or to any other address as may have been furnished to Indemnitee by the Company.

Section 22. Contribution.

(a) To the fullest extent permitted by law, whether or not the indemnification provided in this Agreement is available, in respect of any threatened, pending or completed action, suit or Proceeding in which the Company is jointly liable with Indemnitee (or would be if joined in such action, or Proceeding), the Company shall pay, in the first instance, the entire amount of any judgment or settlement of such action, suit or Proceeding without requiring Indemnitee to contribute to such payment, and the Company hereby waives and relinquishes any right of contribution it may have against Indemnitee. The Company shall not enter into any settlement of any action, suit or Proceeding in which the Company is jointly liable with Indemnitee (or would be if joined in such action, suit or Proceeding) unless such settlement provides for a full and final release of all claims asserted against Indemnitee.

(b) Without diminishing or impairing the obligations of the Company set forth in the preceding subparagraph, if, for any reason, Indemnitee shall elect or be required to pay all or any portion of any judgment or settlement in any threatened, pending or completed action, suit or Proceeding in which the Company is jointly liable with Indemnitee (or would be if joined in such action, suit or Proceeding), the Company shall contribute to the amount of Expenses, judgments, fines and amounts paid in settlement actually and reasonably incurred and paid or payable by Indemnitee in proportion to the relative benefits received by the Company and all officers, directors or employees of the Company, other than Indemnitee, who are jointly liable with Indemnitee (or would be if joined in such action, suit or Proceeding), on the one hand, and Indemnitee, on the other hand, from the transaction or events from which such action, suit or Proceeding arose; provided, however, that the proportion determined on the basis of relative benefit may, to the extent necessary to conform to law, be further adjusted by reference to the relative fault of the Company and all officers, directors or employees of the Company other than Indemnitee who are jointly liable with Indemnitee (or would be if joined in such action, suit or Proceeding), on the one hand, and Indemnitee, on the other hand, in connection with the transaction or events that resulted in such Expenses, judgments, fines or settlement amounts, as well as any other equitable considerations that applicable law may require to be considered.

 

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(c) The Company hereby agrees, to the fullest extent permitted by applicable law, to fully indemnify and hold Indemnitee harmless from any claims of contribution that may be brought by officers, directors or employees of the Company, other than Indemnitee, who may be jointly liable with Indemnitee.

(d) To the fullest extent permissible under applicable law and without diminishing or impairing the obligations of the Company set forth in the preceding subparagraphs of this Section 22, if the indemnification provided for in this Agreement is unavailable to Indemnitee for any reason whatsoever, the Company, in lieu of indemnifying Indemnitee, shall contribute to the amount incurred by Indemnitee, whether for judgments, fines, penalties, excise taxes, amounts paid or to be paid in settlement and/or for Expenses, in connection with any claim relating to an indemnifiable event under this Agreement, in such proportion as is deemed fair and reasonable in light of all of the circumstances of such Proceeding in order to reflect (i) the relative benefits received by the Company and Indemnitee as a result of the event(s) and/or transaction(s) giving cause to such Proceeding; and/or (ii) the relative fault of the Company (and its directors, officers, employees and agents) and Indemnitee in connection with such event(s) and/or transaction(s).

(e) The relative fault of Indemnitee, on the one hand, and of the Company and any and all other parties (including officers and directors of the Company other than Indemnitee) who may be at fault with respect to such matter shall be determined (i) by reference to the relative fault of Indemnitee as determined by the court or other governmental agency assessing the contribution amounts or (ii) to the extent such court or other governmental agency does not apportion relative fault, by the Independent Counsel (or such other party that makes a determination under this Agreement) after giving effect to, among other things, the degree to which their actions were motivated by intent to gain personal profit or advantage, the degree to which their liability is primary or secondary, the degree to which their conduct is active or passive, the degree of the knowledge, access to information, and opportunity to prevent or correct the subject matter of the Proceedings and other relevant equitable considerations of each party. The Company and Indemnitee agree that it would not be just and equitable if contribution pursuant to this Section 22 were determined by pro rata allocation or by any other method of allocation that does not take account of the equitable considerations referred to in this Section 22.

Section 23. Applicable Law and Consent to Jurisdiction. This Agreement and the legal relations among the parties shall be governed by, and construed and enforced in accordance with, the laws of the State of Delaware, without regard to its conflict of laws rules. Except with respect to any arbitration commenced by Indemnitee pursuant to Section 14(a) of this Agreement, the Company and Indemnitee hereby irrevocably and unconditionally (i) agree that any action or proceeding arising out of or in connection with this Agreement shall be brought only in the Chancery Court of the State of Delaware (the “Delaware Court”), and not in any other state or federal court in the United States of America or any court in any other country, (ii) consent to submit to the exclusive jurisdiction of the Delaware Court for purposes of any action or proceeding arising out of or in connection with this Agreement, (iii) appoint, to the extent such party is not otherwise subject to service of process in the State of Delaware, irrevocably Continental Stock Transfer & Trust Company, 1000 North King Street, Wilmington, Delaware 19801 as its agent in the State of Delaware as such party’s agent for acceptance of legal process in connection with any such action or proceeding against such party with the same legal force and validity as if served upon such party personally within the State of Delaware, (iv) waive any objection to the laying of venue of any such action or proceeding in the Delaware Court, and (v) waive, and agree not to plead or to make, any claim that any such action or proceeding brought in the Delaware Court has been brought in an improper or inconvenient forum.

 

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Section 24. Identical Counterparts. This Agreement may be executed in one or more counterparts, each of which shall for all purposes be deemed to be an original but all of which together shall constitute one and the same Agreement. Only one such counterpart signed by the party against whom enforceability is sought needs to be produced to evidence the existence of this Agreement.

Section 25. Miscellaneous. Use of the masculine pronoun shall be deemed to include usage of the feminine pronoun where appropriate. The headings of this Agreement are inserted for convenience only and shall not be deemed to constitute part of this Agreement or to affect the construction thereof.

[Signature Page Follows]

 

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IN WITNESS WHEREOF, the parties have caused this Agreement to be signed as of the day and year first above written.

 

SITIO ROYALTIES CORP.

By:  

 

  Name:
  Title:

 

SIGNATURE PAGE TO

INDEMNIFICATION AGREEMENT


INDEMNITEE
By:  

 

  Name:
  Address:

 

SIGNATURE PAGE TO

INDEMNIFICATION AGREEMENT

Exhibit 10.8

Execution Version

SECOND AMENDED AND RESTATED CREDIT AGREEMENT

DATED AS OF

JUNE 7, 2022

AMONG

SITIO ROYALTIES OPERATING PARTNERSHIP, LP,

AS BORROWER,

BANK OF AMERICA, N.A.,

AS ADMINISTRATIVE AGENT AND ISSUING BANK

AND

THE LENDERS PARTY HERETO

 

 

BARCLAYS BANK PLC, CAPITAL ONE, NATIONAL ASSOCIATION,

FIFTH THIRD BANK, NATIONAL ASSOCIATION AND KEYBANK NATIONAL ASSOCIATION,

AS CO-DOCUMENTATION AGENTS

 

 

BOFA SECURITIES, INC.,

AS SOLE LEAD ARRANGER AND SOLE BOOKRUNNER


TABLE OF CONTENTS

 

         Page  

Article I Definitions and Accounting Matters

     1  

Section 1.01

  Terms Defined Above      1  

Section 1.02

  Certain Defined Terms      2  

Section 1.03

  Rounding      39  

Section 1.04

  Terms Generally; Rules of Construction      39  

Section 1.05

  Accounting Terms and Determinations; GAAP      40  

Section 1.06

  Interest Rates      40  

Section 1.07

  Designation and Conversion of Restricted and Unrestricted Subsidiaries      41  

Section 1.08

  Letter of Credit Amounts      42  

Section 1.09

  Divisions      42  

Article II The Credits

     42  

Section 2.01

  Commitments      42  

Section 2.02

  Loans and Borrowings      42  

Section 2.03

  Requests for Borrowings      44  

Section 2.04

  Interest Elections      45  

Section 2.05

  Funding of Borrowings      46  

Section 2.06

  Termination, Revision and Reduction of Commitments and Aggregate Maximum Credit Amounts; Increase, Reduction and Termination of Aggregate Elected Commitment      47  

Section 2.07

  Borrowing Base      51  

Section 2.08

  Letters of Credit      54  

Article III Payments of Principal and Interest; Prepayments; Fees

     61  

Section 3.01

  Repayment of Loans      61  

Section 3.02

  Interest      61  

Section 3.03

  Inability to Determine Rates      62  

Section 3.04

  Prepayments      64  

Section 3.05

  Fees      67  

Article IV Payments; Pro Rata Treatment; Sharing of Set-offs

     68  

Section 4.01

  Payments Generally; Pro Rata Treatment; Sharing of Set-offs      68  

Section 4.02

  Presumption of Payment by the Borrower      70  

Section 4.03

  Deductions by the Administrative Agent; Defaulting Lenders      70  

Section 4.04

  Disposition of Proceeds      73  

Article V Increased Costs; Break Funding Payments; Taxes; Illegality

     73  

Section 5.01

  Increased Costs      73  

 

i


Section 5.02

  Break Funding Payments      74  

Section 5.03

  Taxes      75  

Section 5.04

  Mitigation Obligations; Replacement of Lenders      78  

Section 5.05

  Illegality      80  

Article VI Conditions Precedent

     81  

Section 6.01

  Effective Date      81  

Section 6.02

  Each Credit Event      83  

Article VII Representations and Warranties

     84  

Section 7.01

  Organization; Powers      84  

Section 7.02

  Authority; Enforceability      84  

Section 7.03

  Approvals; No Conflicts      85  

Section 7.04

  Financial Condition; No Material Adverse Change      85  

Section 7.05

  Litigation      86  

Section 7.06

  Environmental Matters      86  

Section 7.07

  Compliance with the Laws and Agreements; No Defaults      87  

Section 7.08

  Investment Company Act      87  

Section 7.09

  Taxes      87  

Section 7.10

  ERISA      87  

Section 7.11

  Disclosure; No Material Misstatements      87  

Section 7.12

  Insurance      88  

Section 7.13

  Restriction on Liens      88  

Section 7.14

  Subsidiaries      88  

Section 7.15

  Jurisdiction of Organization      88  

Section 7.16

  Properties; Titles, Etc.      88  

Section 7.17

  Maintenance of Properties      89  

Section 7.18

  Gas Imbalances, Prepayments      90  

Section 7.19

  Marketing of Production      90  

Section 7.20

  Swap Agreements and Qualified ECP Counterparty      90  

Section 7.21

  Use of Loans and Letters of Credit      90  

Section 7.22

  Solvency      91  

Section 7.23

  International Operations      91  

Section 7.24

  USA PATRIOT; AML Laws; Anti-Corruption Laws and Sanctions      91  

Section 7.25

  Affected Financial Institution      91  

Article VIII Affirmative Covenants

     92  

Section 8.01

  Financial Statements; Other Information      92  

Section 8.02

  Notices of Material Events      97  

Section 8.03

  Existence; Conduct of Business      97  

Section 8.04

  Payment of Obligations      98  

Section 8.05

  Performance of Obligations under Loan Documents      98  

Section 8.06

  Operation and Maintenance of Properties      98  

Section 8.07

  Insurance      99  

 

ii


Section 8.08

  Books and Records; Inspection Rights      99  

Section 8.09

  Compliance with Laws      99  

Section 8.10

  Environmental Matters      99  

Section 8.11

  Further Assurances      100  

Section 8.12

  Reserve Reports      101  

Section 8.13

  Title Information      102  

Section 8.14

  Additional Collateral; Additional Guarantors      103  

Section 8.15

  ERISA Event      103  

Section 8.16

  Marketing Activities      103  

Section 8.17

  Accounts      104  

Section 8.18

  Unrestricted Subsidiaries      104  

Section 8.19

  Post-Closing Matters      105  

Article IX Negative Covenants

     105  

Section 9.01

 

Financial Covenants

     105  

Section 9.02

 

Debt

     106  

Section 9.03

 

Liens

     108  

Section 9.04

 

Restricted Payments

     109  

Section 9.05

 

Investments, Loans and Advances

     110  

Section 9.06

 

Nature of Business; International Operations

     112  

Section 9.07

 

[Reserved]

     112  

Section 9.08

 

Proceeds of Loans; OFAC

     112  

Section 9.09

 

ERISA Compliance

     112  

Section 9.10

 

Sale or Discount of Receivables

     112  

Section 9.11

 

Mergers, Etc

     113  

Section 9.12

 

Sale of Properties

     113  

Section 9.13

 

Environmental Matters

     115  

Section 9.14

 

Transactions with Affiliates

     115  

Section 9.15

 

Subsidiaries

     115  

Section 9.16

 

Negative Pledge Agreements; Dividend Restrictions

     115  

Section 9.17

 

Gas Imbalances, Take-or-Pay or Other Prepayments

     116  

Section 9.18

 

Swap Agreements

     116  

Section 9.19

 

Amendments to Material Agreements; Amendment to Fiscal Year

     117  

Section 9.20

  Amendments to Terms of the Merger Agreement, Callon Side Letter Assignment and Callon Side Letter      117  

Section 9.21

  Repayment of Permitted Additional Debt; Amendment to Terms of Permitted Additional Debt      117  

Section 9.22

 

Passive Holding Company Status of the Parent and the GP Pledgor

     118  

Article X Events of Default; Remedies

     119  

Section 10.01

 

Events of Default

     119  

Section 10.02

 

Remedies

     121  

 

iii


Article XI The Agents

     123  

Section 11.01

  Appointment; Powers      123  

Section 11.02

  Duties and Obligations of Administrative Agent      123  

Section 11.03

  Action by Administrative Agent      124  

Section 11.04

  Reliance by Administrative Agent      125  

Section 11.05

  Subagents      125  

Section 11.06

  Resignation of Administrative Agent      126  

Section 11.07

  Administrative Agent as Lender      127  

Section 11.08

  No Reliance      127  

Section 11.09

  Administrative Agent May File Proofs of Claim      128  

Section 11.10

  Withholding Tax      128  

Section 11.11

  Authority of Administrative Agent to Release Collateral and Liens      129  

Section 11.12

  [Reserved]      129  

Section 11.13

  Credit Bidding      129  

Section 11.14

  Certain ERISA Matters      130  

Section 11.15

  Recovery of Erroneous Payments      131  

Article XII Miscellaneous

     134  

Section 12.01

  Notices      134  

Section 12.02

  Waivers; Amendments      137  

Section 12.03

  Expenses, Indemnity; Damage Waiver      139  

Section 12.04

  Successors and Assigns      142  

Section 12.05

  Survival; Revival; Reinstatement      146  

Section 12.06

  Integration; ENTIRE AGREEMENT; Effectiveness.      147  

Section 12.07

  Severability      147  

Section 12.08

  Right of Setoff      147  

Section 12.09

  GOVERNING LAW; JURISDICTION; CONSENT TO SERVICE OF PROCESS      148  

Section 12.10

  Headings      149  

Section 12.11

  Confidentiality; Material Non-Public Information      149  

Section 12.12

  Interest Rate Limitation      150  

Section 12.13

  EXCULPATION PROVISIONS      151  

Section 12.14

  Collateral Matters; Swap Agreements; Cash Management Agreements      151  

Section 12.15

  No Third Party Beneficiaries      152  

Section 12.16

  USA PATRIOT Act Notice      152  

Section 12.17

  Non-Fiduciary Status      152  

Section 12.18

  Flood Insurance Provisions      152  

Section 12.19

  Acknowledgement and Consent to Bail-In of Affected Financial Institutions      153  

Section 12.20

  Acknowledgement Regarding Any Supported QFCs      153  

Section 12.21

  Releases      154  

Section 12.22

  Electronic Execution; Electronic Records; Counterparts.      154  

Section 12.23

  Assignment and Assumption from KMF Land to Borrower; Amendment and Restatement; Existing Credit Agreement      155  

 

iv


ANNEXES, EXHIBITS AND SCHEDULES

 

Annex I   List of Applicable Percentage, Maximum Credit Amounts and Elected Commitments
Exhibit A   Form of Note
Exhibit B   Form of Borrowing Request
Exhibit C   Form of Interest Election Request
Exhibit D   Form of Compliance Certificate
Exhibit E   Security Instruments
Exhibit F   Form of Guarantee Agreement
Exhibit G   Form of Assignment and Assumption
Exhibit H-1   Form of U.S. Tax Compliance Certificate
    (Foreign Lenders That Are Not Partnerships)
Exhibit H-2   Form of U.S. Tax Compliance Certificate
    (Foreign Participants That Are Not Partnerships)
Exhibit H-3   Form of U.S. Tax Compliance Certificate
    (Foreign Participants That Are Partnerships)
Exhibit H-4   Form of U.S. Tax Compliance Certificate
    (Foreign Lenders That Are Partnerships)
Exhibit I   Elected Commitment Increase Certificate
Exhibit J   Additional Lender Certificate
Schedule 7.05   Litigation
Schedule 7.14   Subsidiaries and Partnerships
Schedule 7.18   Gas Imbalances; Other Prepayments
Schedule 7.19   Marketing Agreements
Schedule 7.20   Swap Agreements
Schedule 8.19   Post-Closing Matters

 

v


THIS SECOND AMENDED AND RESTATED CREDIT AGREEMENT dated as of June 7, 2022 is among Sitio Royalties Operating Partnership, LP, a Delaware limited partnership formerly known as Falcon Minerals Operating Partnership, LP, a Delaware limited partnership (the “Borrower”), each of the Lenders (as defined below) from time to time party hereto, Bank of America, N.A. (in its individual capacity, “Bank of America”), as Administrative Agent (as defined below) and Issuing Bank (as defined below), and, solely for the purposes of Section 12.23, KMF Land, LLC, a Delaware limited liability company (“KMF Land”).

R E C I T A L S

A.    KMF Land, as borrower, DPM HoldCo, LLC, a Delaware limited liability company (“DPM Holdco”), as parent, the lenders party thereto (the “Existing Lenders”), Bank of America, as administrative agent, and the other parties thereto are party to that certain Amended and Restated Credit Agreement dated as of October 8, 2021 (as amended, supplemented or otherwise modified prior to the Effective Date (as defined below), the “Existing Credit Agreement”), pursuant to which the Existing Lenders have made certain loans to and extensions of credit on behalf of KMF Land for the purposes set forth therein.

B.     Prior to or contemporaneously with the Effective Date, Ferrari Merger Sub A LLC, a Delaware limited liability company and a Wholly-Owned Subsidiary (as defined below) of the Borrower (“Merger Sub”) shall merge with and into DPM Holdco pursuant to the Merger Agreement (as defined below) (the “Merger”), with DPM Holdco surviving the Merger as a direct Wholly-Owned Subsidiary of the Borrower and with KMF Land being an indirect Wholly-Owned Subsidiary of the Borrower after the Merger.

C.    Subject to the conditions precedent set forth herein, the parties hereto desire to (i) allow KMF Land to assign to the Borrower its rights, duties, liabilities and obligations as the borrower under the Existing Credit Agreement and the other “Loan Documents” (as defined in the Existing Credit Agreement) (collectively, the “Existing Loan Documents”) executed in connection with the Existing Credit Agreement, (ii) reflect the reorganization effectuated by the Merger and (iii) amend and restate the Existing Credit Agreement in its entirety in the form of this Agreement.

D.    KMF Land and the Borrower have requested that the Lenders provide certain loans to and extensions of credit on behalf of the Borrower.

E.    The Lenders have agreed to make such loans and extensions of credit subject to the terms and conditions of this Agreement.

F.    In consideration of the mutual covenants and agreements herein contained and of the loans, extensions of credit and commitments hereinafter referred to, the parties hereto agree to amend and restate the Existing Credit Agreement as follows:

ARTICLE I

DEFINITIONS AND ACCOUNTING MATTERS

Section 1.01    Terms Defined Above. As used in this Agreement, each term defined above has the meaning indicated above.

 

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Section 1.02    Certain Defined Terms. As used in this Agreement, the following terms have the meanings specified below:

ABR Borrowing” means any Borrowing comprised of ABR Loans.

ABR Loan” means a Loan bearing interest based on the Alternate Base Rate.

Accounting Changes” refers to changes in accounting principles required by the promulgation of any rule, regulation, pronouncement or opinion by the Financial Accounting Standards Board of the American Institute of Certified Public Accountants or, if applicable, the SEC.

Additional Lender” has the meaning assigned to such term in Section 2.06(c)(i).

Additional Lender Certificate” has the meaning assigned to such term in Section 2.06(c)(ii)(H).

Administrative Agent” means Bank of America in its capacity as administrative agent hereunder, or any successor administrative agent as provided in Section 11.06.

Administrative Questionnaire” means an administrative questionnaire in a form supplied by the Administrative Agent.

Affected Financial Institution” means (a) any EEA Financial Institution or (b) any UK Financial Institution.

Affiliate” means, with respect to a specified Person, another Person that directly, or indirectly through one or more intermediaries, Controls or is Controlled by or is under common Control with the Person specified.

Agent” means each of the Administrative Agent and any syndication agent, documentation agent or other agent or sub-agent pursuant to Section 11.05 appointed by the Administrative Agent with respect to matters related to the Loan Documents (including any trustee appointed pursuant to any mortgage or deed of trust, in each case, to the extent constituting a Security Instrument).

Aggregate Elected Commitment” means, at any time, an amount equal to the sum of the aggregate Elected Commitments, as the same may be increased, reduced or terminated pursuant to Section 2.06(c). The Aggregate Elected Commitment as of the Effective Date is $300,000,000.

Aggregate Maximum Credit Amounts” at any time shall equal the sum of the Maximum Credit Amounts in effect at such time, as the same may be reduced or terminated pursuant to Section 2.06(b). The Aggregate Maximum Credit Amounts as of the Effective Date is $750,000,000.

Agreement” means this Second Amended and Restated Credit Agreement, including the Annexes, Schedules and Exhibits hereto, as the same may from time to time be amended, modified, supplemented or restated.

Alternate Base Rate” means, for any day, a fluctuating rate per annum equal to the greatest of (a) the Prime Rate in effect on such day as publicly announced from time to time by the Administrative Agent, (b) the Federal Funds Rate in effect on such day plus 12 of 1.0%, (c) Term SOFR plus

 

2


1.00% and (d) 1.00%. Any change in the Alternate Base Rate due to a change in the Prime Rate, the Federal Funds Rate or Term SOFR shall be effective from and including the effective date of such change in the Prime Rate, the Federal Funds Rate or Term SOFR, respectively. If the Alternate Base Rate is being used as an alternate rate of interest pursuant to Section 3.03 hereof, then the Alternate Base Rate shall be the greater of clause (a), (b) and (d) above and shall be determined without reference to clause (c) above.

AML Laws” means the USA Patriot Act and all other laws, rules, and regulations of any jurisdiction applicable to any Lender, the Borrower, the Subsidiaries or any Guarantor from time to time concerning or relating to anti-money laundering.

Anti-Corruption Laws” means the United States Foreign Corrupt Practices Act of 1977, the UK Bribery Act 2010 and all other laws, rules, and regulations of any jurisdiction applicable to the Borrower or the Subsidiaries from time to time concerning or relating to bribery or corruption.

Applicable Margin” means, for any day, with respect to any ABR Loan or Term SOFR Loan, or with respect to the Commitment Fee Rate, as the case may be, the rate per annum set forth in the Borrowing Base Utilization Grid below based upon the Borrowing Base Utilization Percentage then in effect:

Borrowing Base Utilization Grid

 

Borrowing Base Utilization Percentage

     <25.0  
 
25.0%, but
<50.0
 
 
 
50.0%, but
<75.0
 
 
 
75.0%, but
<90.0
 
    ≥90.0

ABR Loan Margin

     1.500     1.750     2.000     2.250     2.500

Term SOFR Loan Margin

     2.500     2.750     3.000     3.250     3.500

Commitment Fee Rate

     0.375     0.375     0.500     0.500     0.500

Each change in the Applicable Margin and the Commitment Fee Rate shall apply during the period commencing on the effective date of such change in the Borrowing Base Utilization Percentage and ending on the date immediately preceding the effective date of the next such change; provided, however, that if at any time the Borrower fails to deliver a Reserve Report pursuant to Section 8.12(a), then the “Applicable Margin” and the “Commitment Fee Rate” shall mean the rate per annum set forth on the grid when the Borrowing Base Utilization Percentage is at its highest level, until such Reserve Report is delivered.

Applicable Parties” has the meaning assigned to such term in Section 12.01(d)(iii).

Applicable Percentage” means, with respect to any Lender at any time, the percentage of the Aggregate Maximum Credit Amounts represented by such Lender’s Maximum Credit Amount; provided that if the Commitments have terminated or expired, each Lender’s Applicable Percentage shall be determined based upon the Commitments most recently in effect.

 

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Approved Counterparty” means (a) any Lender or any Affiliate of a Lender, (b) any other Person whose (or, if such Person’s obligations under the applicable Swap Agreement are guaranteed by such Person’s Affiliate, whose Affiliate’s) long term senior unsecured debt rating is A-/A3 by S&P or Moody’s (or their equivalent) or higher, and (c) any other Person that is reasonably acceptable to the Administrative Agent in its sole discretion.

Approved Electronic Platform” means IntraLinks, DebtDomain, SyndTrak, ClearPar or any other electronic platform chosen by the Administrative Agent to be its electronic transmission system.

Approved Fund” means any Person (other than a natural person) that is (or will be) engaged in making, purchasing, holding or otherwise investing in commercial loans and similar extensions of credit in the ordinary course of its activities and that is administered or managed by (a) a Lender, (b) an Affiliate of a Lender or (c) an entity or an Affiliate of an entity that administers or manages a Lender.

Approved Petroleum Engineers” means (a) Ryder Scott Company Petroleum Consultants, L.P., (b) Cawley, Gillespie & Associates, Inc., (c) Netherland, Sewell & Associates, Inc., (d) DeGolyer and MacNaughton and (e) any other independent petroleum engineers reasonably acceptable to the Administrative Agent.

Arranger” means BofA Securities, Inc., in its capacity as sole lead arranger and sole bookrunner hereunder.

Assignment and Assumption” means an assignment and assumption entered into by a Lender and an assignee (with the consent of any party whose consent is required by Section 12.04(b)), and accepted by the Administrative Agent, in the form of Exhibit G or any other form approved by the Administrative Agent.

Availability Period” means the period from and including the Effective Date until the Termination Date.

Bail-In Action” means the exercise of any Write-Down and Conversion Powers by the applicable Resolution Authority in respect of any liability of an Affected Financial Institution.

Bail-In Legislation” means, (a) with respect to any EEA Member Country implementing Article 55 of Directive 2014/59/EU of the European Parliament and of the Council of the European Union, the implementing law, rule, regulation or requirement for such EEA Member Country from time to time which is described in the EU Bail-In Legislation Schedule, and (b) with respect to the United Kingdom, Part I of the United Kingdom Banking Act 2009 (as amended from time to time) and any other law, regulation or rule applicable in the United Kingdom relating to the resolution of unsound or failing banks, investment firms or other financial institutions or their affiliates (other than through liquidation, administration or other insolvency proceedings).

Bank of America” has the meaning set forth in the preamble.

 

4


Bankruptcy Event” means, with respect to any Person, such Person becomes the subject of a bankruptcy or insolvency proceeding, or has had a receiver, conservator, trustee, administrator, custodian, assignee for the benefit of creditors or similar Person charged with the reorganization or liquidation of its business appointed for it, or, in the good faith determination of the Administrative Agent, has taken any action in furtherance of, or indicating its consent to, approval of, or acquiescence in, any such proceeding or appointment; provided that a Bankruptcy Event shall not result solely by virtue of any ownership interest, or the acquisition of any ownership interest, in such Person by a Governmental Authority or instrumentality thereof; provided, further, that such ownership interest does not result in or provide such Person with immunity from the jurisdiction of courts within the United States or from the enforcement of judgments or writs of attachment on its assets or permit such Person (or such Governmental Authority or instrumentality) to reject, repudiate, disavow or disaffirm any contracts or agreements made by such Person.

Beneficial Ownership Certification” means a certification regarding beneficial ownership or control as required by the Beneficial Ownership Regulation.

Beneficial Ownership Regulation” means 31 C.F.R. § 1010.230.

BHC Act Affiliate” of a party means an “affiliate” (as such term is defined under, and interpreted in accordance with, 12 U.S.C. 1841(k)) of such party.

Board” means the Board of Governors of the Federal Reserve System of the United States of America or any successor Governmental Authority.

Borrower” has the meaning set forth in the preamble.

Borrowing” means Loans of the same Type, made, converted or continued on the same date and, in the case of a Term SOFR Borrowing, as to which a single Interest Period is in effect.

Borrowing Base” means at any time an amount equal to the amount determined in accordance with Section 2.07, as the same may be adjusted from time to time pursuant to Section 2.07(e), Section 2.07(f) or Section 8.13(c).

Borrowing Base Deficiency” occurs if at any time the total Revolving Credit Exposures exceeds the Borrowing Base then in effect. The amount of the Borrowing Base Deficiency at such time is the amount by which the total Revolving Credit Exposures exceeds the Borrowing Base then in effect; provided, that, for purposes of determining the existence and amount of any Borrowing Base Deficiency, obligations under any Letter of Credit will not be deemed to be outstanding to the extent such obligations are cash collateralized or otherwise backstopped in such amounts and pursuant to such arrangements as are satisfactory to the Issuing Bank in its sole discretion.

Borrowing Base Properties” means the proved Oil and Gas Properties of the Loan Parties included in the most recently delivered Reserve Report hereunder (including, for the avoidance of doubt, the Initial Reserve Report).

Borrowing Base Utilization Percentage” means, as of any day, the fraction expressed as a percentage, the numerator of which is the sum of the Revolving Credit Exposures of the Lenders on such day, and the denominator of which is the Borrowing Base in effect on such day.

 

5


Borrowing Request” means a request by the Borrower substantially in the form of Exhibit B or otherwise reasonably acceptable to the Administrative Agent for a Borrowing in accordance with Section 2.03.

Business Day” means any day that is not a Saturday, Sunday or other day on which commercial banks in New York City, New York are authorized or required by law to remain closed or are in fact closed.

Callon Side Letter” means that certain letter agreement, dated as of September 30, 2020, by and among Chambers Minerals, Callon Petroleum Operating Company, a Delaware corporation, and the other parties thereto, as amended, restated, supplemented or otherwise modified as permitted hereunder.

Callon Side Letter Assignment” means the Partial Assignment and Assumption Agreement, effective as of June 30, 2021, by and between Chambers Minerals and KMF Land, as amended, restated, supplemented or otherwise modified as permitted hereunder.

Capital Leases” means, in respect of any Person, all leases which shall have been, or should have been, in accordance with GAAP, recorded as capital (or finance) leases on the balance sheet of the Person liable (whether contingent or otherwise) for the payment of rent thereunder. It is understood that this definition is subject to the terms and conditions set forth in Section 1.05.

Cash Equivalents” means any of the following types of Investments:

 

(a)

direct obligations of the United States or any agency thereof, or obligations guaranteed by the United States or any agency or instrumentality thereof, in each case maturing within one year from the date of any Loan Party’s acquisition thereof;

 

(b)

commercial paper maturing within one year from the date of any Loan Party’s acquisition thereof rated no lower than A2 or P2, as such rating is set forth from time to time, by S&P or Moody’s, respectively;

 

(c)

deposits (including, but not limited to, certificates of deposit, time deposits, banker’s acceptances, and overnight bank deposits) maturing within one year from the date of any Loan Party’s acquisition thereof with (or issued by) any Lender or any office located in the United States of any other bank or trust company which is organized under the laws of the United States or any state thereof, which has capital, surplus and undivided profits aggregating at least $100,000,000 (as of the date of such bank or trust company’s most recent financial reports) and has a short term deposit rating of no lower than A2 or P2, as such rating is set forth from time to time, by S&P or Moody’s, respectively;

 

(d)

Dollars;

 

(e)

marketable short-term money market and similar funds (including such funds investing a portion of their assets in municipal securities) having a rating of at least A2 or P2, as such rating is set forth from time to time, by S&P or Moody’s, respectively;

 

6


(f)

repurchase obligations for underlying securities of the types described in clauses (a), (b), (c), and (e) entered into with any financial institution meeting the qualifications specified in clause (c) above;

 

(g)

readily marketable direct obligations, with average maturities of one year or less from the date of any Loan Party’s acquisition thereof, issued by any state, commonwealth, or territory of the United States, or any political subdivision or taxing authority thereof, having one of the two highest rating categories obtainable from either S&P or Moody’s; and

 

(h)

Investments in investment funds or deposits in money market funds investing at least 95% of their assets in securities of the types (including as to credit quality and maturity) described in clauses (a) through (g) above.

Cash Management Agreement” means any agreement to provide cash management services, including treasury, depository, overdraft, credit or debit card, electronic funds transfer and other cash management services.

Cash Receipts” means all cash received by or on behalf of the Loan Parties, including without limitation: (a) any amounts payable under or in connection with any Oil and Gas Properties; (b) cash representing operating revenue earned or to be earned by the Loan Parties; (c) proceeds from Loans; and (d) any other cash received by the Loan Parties from whatever source (including, without limitation, amounts received in respect of the Liquidation of any Swap Agreement).

Casualty Event” means any loss, casualty or other insured damage to, or any nationalization, taking under power of eminent domain or by condemnation or similar proceeding of, any Property of the Loan Parties.

Chambers Minerals” means Chambers Minerals, LLC, a Delaware limited liability company.

Change in Control” means the occurrence of any of the following:

 

(a)

(i) any “person” or “group” (within the meaning of Rules 13(d) and 14(d) of the Exchange Act), other than the Permitted Holders (or any Persons that are wholly-owned (directly or indirectly), and Controlled, by the Permitted Holders), shall have acquired beneficial ownership (within the meaning of Rules 13d-3 and 13d-5 of the Exchange Act) or Control of 35.0% or more on a fully diluted basis of the voting interest in the Equity Interests of Parent necessary for the election of directors of Parent or (ii) the occupation of a majority of the seats (other than vacant seats) on the board of directors of Parent by Persons who were neither (1) directors of Parent on the Effective Date, (2) nominated nor approved by the board of directors of Parent nor (3) appointed by directors so nominated or approved;

 

(b)

Parent shall cease to Control the GP Pledgor;

 

(c)

the GP Pledgor shall cease to be the sole general partner of the Borrower; or

 

(d)

at any time, a “Change in Control” (or similar event howsoever described or howsoever defined) occurs under any Permitted Additional Debt.

 

7


Notwithstanding the preceding or any provision of Section 13d-3 of the Exchange Act, (i) a Person or group shall not be deemed to beneficially own Equity Interest subject to a stock or asset purchase agreement, merger agreement, option agreement, warrant agreement or similar agreement (or voting or option or similar agreement related thereto) until the consummation of the acquisition of the Equity Interests in connection with the transactions contemplated by such agreement and (ii) if any group includes one or more Permitted Holders, the issued and outstanding Equity Interests owned, directly or indirectly, and as to which sole and exclusive voting power with respect to, and authority over the disposition of, such Equity Interests is retained at any time of determination, by any such Permitted Holders that are part of such group shall be treated as being beneficially owned by such Permitted Holders and shall not be treated as being beneficially owned by such group or any other member of such group for purposes of determining whether a Change in Control has occurred.

Change in Law” means the occurrence after the date of this Agreement or, with respect to any Lender, such later date on which such Lender becomes a party to this Agreement of (a) the adoption of or taking effect of any law, rule, regulation or treaty, (b) any change in any law, rule, regulation or treaty or in the administration, interpretation, implementation or application thereof by any Governmental Authority or (c) compliance by any Lender or the Issuing Bank (or, for purposes of Section 5.01(b), by any lending office of such Lender or by such Lender’s or the Issuing Bank’s holding company, if any) with any request, guideline or directive (whether or not having the force of law) of any Governmental Authority made or issued after the date of this Agreement; provided that, notwithstanding anything herein to the contrary, (x) the Dodd-Frank Wall Street Reform and Consumer Protection Act and all requests, rules, guidelines, requirements or directives thereunder or issued in connection therewith (whether or not having the force of law) or in implementation thereof and (y) all requests, rules, guidelines or directives promulgated by the Bank for International Settlements, the Basel Committee on Banking Supervision (or any successor or similar authority) or the United States or foreign regulatory authorities, in each case pursuant to Basel III, shall, in each case, be deemed to be a “Change in Law,” regardless of the date enacted, adopted, promulgated, issued or implemented.

CME” means CME Group Benchmark Administration Limited.

Code” means the Internal Revenue Code of 1986, as amended from time to time, and any successor statute.

Collateral” means all Property of the Borrower and the Guarantors now owned or hereafter acquired which is subject to a Lien created or purported to be created under one or more Security Instruments; provided that, the Collateral shall not include Excluded Property.

Commitment” means, with respect to each Lender, the commitment of such Lender to make or continue Loans and to acquire participations in Letters of Credit hereunder, expressed as an amount representing the maximum aggregate amount of such Lender’s Revolving Credit Exposure hereunder, as such commitment may be (a) modified from time to time pursuant to Section 2.06, (b) modified from time to time pursuant to assignments by or to such Lender pursuant to Section 12.04(b) or (c) otherwise modified pursuant to this Agreement. The amount representing each Lender’s Commitment shall at any time be the lesser of (i) such Lender’s Maximum Credit Amount, (ii) such Lender’s Elected Commitment and (iii) such Lender’s Applicable Percentage of the then effective Borrowing Base.

 

8


Commitment Fee Rate” has the meaning set forth in the definition of “Applicable Margin”.

Commodity Account” has the meaning assigned to such term in the UCC.

Communications” means this Agreement, any Loan Document and any document, any amendment, approval, consent, information, notice, certificate, request, statement, disclosure or authorization related to any Loan Document.

Conforming Changes” means, with respect to the use, administration of or any conventions associated with SOFR or any proposed Successor Rate or Term SOFR, as applicable, any conforming changes to the definitions of “Alternate Base Rate, “SOFR”, “Term SOFR” and “Interest Period”, timing and frequency of determining rates and making payments of interest and other technical, administrative or operational matters (including, for the avoidance of doubt, the definitions of “Business Day” and “U.S. Government Securities Business Day”, timing of borrowing requests or prepayment, conversion or continuation notices and length of lookback periods) as may be appropriate, in the discretion of the Administrative Agent, to reflect the adoption and implementation of such applicable rate(s) and to permit the administration thereof by the Administrative Agent in a manner substantially consistent with market practice (or, if the Administrative Agent determines that adoption of any portion of such market practice is not administratively feasible or that no market practice for the administration of such rate exists, in such other manner of administration as the Administrative Agent determines is reasonably necessary in connection with the administration of this Agreement and any other Loan Document).

Connection Income Taxes” means Other Connection Taxes that are imposed on or measured by net income (however denominated) or that are franchise Taxes or branch profits Taxes.

Consolidated Net Income” means with respect to the Borrower and the Consolidated Restricted Subsidiaries, for any period, the aggregate of the net income (or loss) of the Borrower and the Consolidated Restricted Subsidiaries after allowances for taxes for such period determined on a consolidated basis in accordance with GAAP; provided that there shall be excluded from such net income (to the extent otherwise included therein) the following: (a) the net income of (i) any Unrestricted Subsidiary and (ii) any Person in which the Borrower or any Consolidated Restricted Subsidiary has an interest (which interest does not cause the net income of such other Person to be consolidated with the net income of the Borrower and the Consolidated Restricted Subsidiaries in accordance with GAAP), except, in the case of the foregoing clauses (i) and (ii), to the extent of the amount of dividends or distributions actually paid in cash during such period by such Unrestricted Subsidiary or other Person, as the case may be, to the Borrower or to a Consolidated Restricted Subsidiary, as the case may be; (b) the net income (but not loss) during such period of any Consolidated Restricted Subsidiary to the extent that the declaration or payment of dividends or similar distributions or transfers or loans by that Consolidated Restricted Subsidiary is not at the time permitted by operation of the terms of its charter or any agreement, instrument or Governmental Requirement applicable to such Consolidated Restricted Subsidiary or is otherwise restricted or prohibited, in each case determined in accordance with GAAP; (c) the net income (or deficit) of any Person accrued prior to the date it becomes a Consolidated Restricted Subsidiary or

 

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is merged into or consolidated with the Borrower or any of its Consolidated Restricted Subsidiaries; (d) any extraordinary gains or losses during such period; (e) any gains or losses attributable to writeups or writedowns of assets; and (f) any non-cash gains or losses or positive or negative adjustments under FASB ASC 815 as a result of changes in the fair market value of derivatives.

Consolidated Restricted Subsidiaries” means any Restricted Subsidiaries that are Consolidated Subsidiaries.

Consolidated Subsidiaries” means each Subsidiary of the Borrower (whether now existing or hereafter created or acquired) the financial statements of which shall be (or should have been) consolidated with the financial statements of the Borrower in accordance with GAAP; provided that when used in reference to any Person other than the Borrower, the term “Consolidated Subsidiaries” means each subsidiary of such Person (whether now existing or hereafter created or acquired), including the Borrower, the financial statements of which shall be (or should have been) consolidated with the financial statements of such Person in accordance with GAAP.

Consolidated Total Assets” means, at any date, the total assets of the Loan Parties determined on a consolidated basis in accordance with GAAP.

Consolidated Unrestricted Subsidiaries” means any Unrestricted Subsidiaries that are Consolidated Subsidiaries.

consolidation” has the meaning assigned to such term in Section 9.11.

Control” means the possession, directly or indirectly, of the power to direct or cause the direction of the management or policies of a Person, whether through the ability to exercise voting power, by contract or otherwise. “Controlling” and “Controlled” have meanings correlative thereto.

Control Agreement” means a control agreement, in form and substance reasonably satisfactory to the Administrative Agent, providing for the Administrative Agent’s control of a Deposit Account, Securities Account or Commodity Account, as applicable, after notice, executed and delivered by the Borrower or any other Loan Party, as applicable, and the applicable securities intermediary (with respect to a Securities Account), bank (with respect to a Deposit Account) or commodity intermediary (with respect to a Commodity Account), in each case at which such relevant account is maintained.

Control Agreement Delivery Date” has the meaning assigned to such term in Section 8.17.

Covered Entity” means any of the following: (i) a “covered entity” as that term is defined in, and interpreted in accordance with, 12 C.F.R. § 252.82(b); (ii) a “covered bank” as that term is defined in, and interpreted in accordance with, 12 C.F.R. § 47.3(b); or (iii) a “covered FSI” as that term is defined in, and interpreted in accordance with, 12 C.F.R. § 382.2(b).

Covered Party” has the meaning assigned to such term in Section 12.20.

Credit Event” means and includes the making (but not the conversion or continuation) of a Loan and the issuance of a Letter of Credit.

 

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Credit Party” means the Administrative Agent, the Issuing Bank or any Lender.

Cure Period” has the meaning assigned to such term in Section 9.01(c).

Current Ratio” has the meaning assigned to such term in Section 9.01(b).

Daily Simple SOFR” with respect to any applicable determination date means the SOFR published on such date on the Federal Reserve Bank of New York’s website (or any successor source).

Debt” means, for any Person, the sum of the following (without duplication):

 

(a)

all obligations of such Person for borrowed money or evidenced by bonds, bankers’ acceptances, debentures, notes or other similar instruments;

 

(b)

all reimbursement obligations of such Person (whether contingent or otherwise) in respect of letters of credit, surety or other bonds and similar instruments;

 

(c)

all accounts payable and all accrued expenses, liabilities or other obligations of such Person to pay the deferred purchase price of Property or services (excluding accounts payable and accrued expenses, liabilities or other obligations of such Person to pay the deferred purchase price of Property or services from time to time incurred in the ordinary course of business which are not greater than ninety (90) days past the date of invoice or delinquent or which are being contested in good faith by appropriate action and for which adequate reserves have been maintained in accordance with GAAP);

 

(d)

all obligations under Capital Leases;

 

(e)

all obligations under Synthetic Leases;

 

(f)

all Debt (as defined in the other clauses of this definition) of others secured by (or for which the holder of such Debt has an existing right, contingent or otherwise, to be secured by) a Lien on any Property of such Person, whether or not such Debt is assumed by such Person;

 

(g)

all Debt (as defined in the other clauses of this definition) of others guaranteed by such Person or in which such Person otherwise assures a creditor against loss of the Debt (howsoever such assurance shall be made) to the extent of the lesser of the amount of such Debt and the maximum stated amount of such guarantee or assurance against loss;

 

(h)

all obligations or undertakings of such Person to maintain or cause to be maintained the financial position or covenants of others or to purchase the Debt or Property of others;

 

(i)

obligations to deliver commodities, goods or services, including, without limitation, Hydrocarbons, in consideration of one or more advance payments, other than gas balancing arrangements in the ordinary course of business;

 

(j)

obligations to pay for goods or services even if such goods or services are not actually received or utilized by such Person;

 

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(k)

any Debt of a partnership for which such Person is liable either by agreement, by operation of law or by a Governmental Requirement but only to the extent of such liability;

 

(l)

Disqualified Capital Stock; and

 

(m)

the undischarged balance of any production payment created by such Person or for the creation of which such Person directly or indirectly received payment.

The Debt of any Person shall include all obligations of such Person of the character described above to the extent such Person remains legally liable in respect thereof notwithstanding that any such obligation is not included as a liability of such Person under GAAP.

Default” means any event or condition which constitutes an Event of Default or which upon notice, lapse of time or both would, unless cured or waived, become an Event of Default.

Default Right” has the meaning assigned to that term in, and shall be interpreted in accordance with, 12 C.F.R. §§ 252.81, 47.2 or 382.1, as applicable.

Defaulting Lender” means any Lender that (a) has failed, within two Business Days of the date required to be funded or paid, to (i) fund any portion of its Loans, (ii) fund any portion of its participations in Letters of Credit or (iii) pay over to any Credit Party any other amount required to be paid by it hereunder, unless, in the case of clause (i) above, such Lender notifies the Administrative Agent in writing that such failure is the result of such Lender’s good faith determination that a condition precedent to funding (specifically identified and including the particular default, if any) has not been satisfied (b) has notified the Borrower or any Credit Party in writing, or has made a public statement to the effect, that it does not intend or expect to comply with any of its funding obligations under this Agreement (unless such writing or public statement indicates that such position is based on such Lender’s good faith determination that a condition precedent (specifically identified and including the particular default, if any) to funding a Loan under this Agreement cannot be satisfied) or generally under other agreements in which it commits to extend credit, (c) has failed, within three Business Days after request by a Credit Party, acting in good faith, to provide a certification in writing from an authorized officer of such Lender that it will comply with its obligations (and is financially able to meet such obligations as of the date of certification) to fund prospective Loans and participations in then outstanding Letters of Credit under this Agreement; provided that such Lender shall cease to be a Defaulting Lender pursuant to this clause (c) upon such Credit Party’s receipt of such certification in form and substance satisfactory to it and the Administrative Agent, or (d) has, or whose Lender Parent has, become the subject of (i) a Bankruptcy Event or (ii) a Bail-In Action. Any determination by the Administrative Agent that a Lender is a Defaulting Lender under any one or more of clauses (a) through (d) above, and of the effective date of such status, shall be conclusive and binding absent manifest error, and such Lender shall be deemed to be a Defaulting Lender (subject to the last paragraph of Section 4.03(c)) as of the date established therefor by the Administrative Agent in a written notice of such determination, which shall be delivered by the Administrative Agent to the Borrower, the Issuing Bank and each other Lender promptly following such determination.

Deposit Account” has the meaning assigned to such term in the UCC.

 

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Disposition” means any conveyance, sale, lease, sale and leaseback, assignment, farm-out, transfer or other disposition of any Property, and includes, for the avoidance of doubt, any Casualty Event. “Dispose” and “Disposed” have correlative meanings thereto. It is understood and agreed that “Disposition” and “Dispose” and “Disposed” shall not be deemed to include any issuance by the Parent of any of its Equity Interests to another Person or by the Borrower or any Restricted Subsidiary of any of its Equity Interests to the Parent, the Borrower or another Restricted Subsidiary.

Disqualified Capital Stock” means any Equity Interest that, by its terms (or by the terms of any security into which it is convertible or for which it is exchangeable) or upon the happening of any event, matures or is mandatorily redeemable for any consideration other than other Equity Interests (which would not constitute Disqualified Capital Stock), pursuant to a sinking fund obligation or otherwise, or is convertible or exchangeable for Debt or redeemable for any consideration other than other Equity Interests (which would not constitute Disqualified Capital Stock) at the option of the holder thereof, in whole or in part (but if in part, only with respect to such amount that meets the criteria set forth in this definition), on or prior to the date that is one year after the earlier of (a) the Maturity Date and (b) the date on which there are no Loans, LC Exposure or other obligations hereunder outstanding and all of the Commitments are terminated.

Dollars” or “$” refers to lawful money of the United States of America.

Domestic Subsidiary” means any Restricted Subsidiary that is organized under the laws of the United States of America or any state thereof or the District of Columbia.

DPM Holdco” has the meaning set forth in the recitals hereto.

Duplicated G&A Expenses” means, for the period ending June 30, 2022, duplicative expenses and operating costs projected by the Borrower in good faith to be eliminated following the consummation of the Merger and acceptable to the Administrative Agent; provided that Public Company Compliance costs and related expenses shall not be included as Duplicated G&A Expenses.

EBITDA” means, with respect to the Borrower and its Consolidated Restricted Subsidiaries, for any period, the sum of:

(a)    Consolidated Net Income for such period, plus

(b)    the following expenses or charges to the extent deducted from Consolidated Net Income in such period:

(i)    interest expense,

(ii)    provision for taxes based on income or profits or capital, including federal and state income taxes, franchise taxes and similar taxes (such as the Delaware franchise tax),

(iii)    depreciation, depletion, amortization, and other similar noncash charges (including any provision for the reduction in the carrying value of assets recorded in accordance with GAAP and including non-cash charges and losses resulting from the requirements of ASC 815),

 

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(iv)    one-time transaction costs and expenses (including, for the avoidance of doubt, legal and accounting costs and expenses, retention charges and severance costs) incurred in connection with the negotiation, execution, delivery and consummation of (A) the Transactions, (B) the other transactions contemplated by this Agreement and the other Loan Documents and (C) the transactions expressly permitted by the Existing Credit Agreement and the other “Loan Documents” as described in the Existing Credit Agreement which occurred prior to the Effective Date,

(v)    unusual and nonrecurring expenses reasonably acceptable to the Administrative Agent,

(vi)    any fees, costs or expenses arising from any management equity plan, stock option plan, the grant of stock appreciation or similar rights, any other rights or equity incentive plan, any other management or employee benefit plan or agreement, and any stock subscription or shareholder agreement; provided that the aggregate amount of addbacks to EBITDA under this clause (vi) and clause (vii) below, individually or in the aggregate shall not exceed 10% of EBITDA for any Reference Period (as defined below), calculated prior to giving effect to such addbacks,

(vii)    any fees, expenses or charges incurred for such period, or any amortization thereof for such period, in connection with any acquisition, incurrence of Debt, Investment, or Disposition (in each case, whether or not any such transaction is completed but only if such acquisition, incurrence of Debt, Investment or Disposition is not in the ordinary course of business); provided that the aggregate amount of addbacks to EBITDA under clause (vi) above and this clause (vii), individually or in the aggregate shall not exceed 10% of EBITDA for any Reference Period (as defined below), calculated prior to giving effect to such addbacks, minus

(c) to the extent included in the statement of Consolidated Net Income for such period, the sum of (1) interest income, (2) income tax credits (to the extent not netted from income tax expense), (3) all noncash income added to Consolidated Net Income, (4) any cash payments made during such period in respect of items described in clause (b)(iii) above subsequent to the fiscal quarter in which the relevant non-cash expenses or charges were reflected as a charge in the statement of Consolidated Net Income and (5) gains on asset Dispositions, disposals and abandonments. For the purposes of calculating EBITDA for any period of four consecutive fiscal quarters (each, a “Reference Period”), (i) if during such Reference Period the Borrower or any Consolidated Restricted Subsidiary shall have made (A) a Material Disposition, EBITDA for such Reference Period shall be calculated on a pro forma basis as if such Material Disposition occurred on the first day of such Reference Period and (B) any Disposition of Property or series of related Dispositions of Property other than a Material Disposition, EBITDA for such Reference Period may, at the election of the Borrower, be calculated on a pro forma basis as if such Disposition of Property or series of related Dispositions of Property occurred on the first day of such Reference Period, (ii) if during such Reference Period the Borrower or any Consolidated Restricted Subsidiary shall have made (A) a Material Acquisition, EBITDA for such Reference Period shall be calculated on a pro forma basis as if such Material Acquisition occurred on the first day of such

 

14


Reference Period, provided, however, that if the EBITDA generated from such Material Acquisition would result in an increase of EBITDA, EBITDA for such Reference Period may, at the election of the Borrower, be calculated on a pro form basis as if such acquisition or series of related acquisitions occurred on the first day of such Reference Period, and (B) any acquisition of Property or series of related acquisitions of Property other than a Material Acquisition, EBITDA for such Reference Period may, at the election of the Borrower, be calculated on a pro forma basis as if such acquisition or series of related acquisitions occurred on the first day of such Reference Period and (iii) if during such Reference Period a Consolidated Subsidiary shall be designated as either a Consolidated Unrestricted Subsidiary or a Consolidated Restricted Subsidiary, EBITDA shall be calculated on a pro forma basis as if such designation had occurred on the first day of such Reference Period. For purposes of determining EBITDA for the Reference Period ending (a) March 31, 2022 and June 30, 2022, EBITDA shall be calculated on a pro forma basis as if the Merger had occurred on the first day of the applicable Reference Period; provided that Duplicated G&A Expenses shall be added back to EBITDA, (b) September 30, 2022, EBITDA shall be calculated as EBITDA for the fiscal quarter ending September 30, 2022 multiplied by four, (c) December 31, 2022, EBITDA shall be calculated as EBITDA for the two consecutive fiscal quarters ending December 31, 2022 multiplied by two, and (d) March 31, 2023, EBITDA shall be calculated as EBITDA for the three consecutive fiscal quarters ending March 31, 2023 multiplied by 4/3.

EEA Financial Institution” means (a) any credit institution or investment firm established in any EEA Member Country that is subject to the supervision of an EEA Resolution Authority, (b) any entity established in an EEA Member Country that is a parent of an institution described in clause (a) of this definition, or (c) any financial institution established in an EEA Member Country that is a subsidiary of an institution described in clauses (a) or (b) of this definition and is subject to consolidated supervision with its parent.

EEA Member Country” means any of the member states of the European Union, Iceland, Liechtenstein, and Norway.

EEA Resolution Authority” means any public administrative authority or any Person entrusted with public administrative authority of any EEA Member Country (including any delegee) having responsibility for the resolution of any EEA Financial Institution.

Effective Date” means the date on which the conditions specified in Section 6.01 are satisfied (or waived in accordance with Section 12.02).

Effective Date Refinancing” means the repayment in full of all third party Debt of the Borrower and its Subsidiaries existing prior to the Effective Date (other than Debt permitted pursuant to Section 9.02), and the termination and release of all commitments, security interests and guarantees in connection therewith.

Elected Commitment” means, as to each Lender, the amount set forth opposite such Lender’s name on Annex I under the caption “Elected Commitment”, as the same may be increased, reduced or terminated from time to time in connection with an optional increase, reduction or termination of the Aggregate Elected Commitment pursuant to Section 2.06(b) or (c).

 

15


Elected Commitment Increase Certificate” has the meaning assigned to such term in Section 2.06(c)(ii)(G).

Electronic Copy” has the meaning assigned to such term in Section 12.22(a).

Electronic Record” has the meaning assigned to such term by 15 USC §7006, as it may be amended from time to time.

Electronic Signature” has the meaning assigned to such term by 15 USC §7006, as it may be amended from time to time.

Engineering Reports” has the meaning assigned to such term in Section 2.07(c)(i).

Environmental Laws” means any and all Governmental Requirements pertaining to pollution or the preservation of the environment, natural resources, or human health and safety (as it relates to exposure to Hazardous Materials), or the management, Release or threatened Release of any Hazardous Materials, in effect in any and all jurisdictions in which the Borrower or any Subsidiary is conducting, or at any time has conducted business, or where any Property of the Borrower or any Subsidiary is located, including the Oil Pollution Act of 1990, as amended, the Clean Air Act, as amended, the Comprehensive Environmental, Response, Compensation, and Liability Act of 1980, as amended, the Federal Water Pollution Control Act, as amended, the Occupational Safety and Health Act of 1970, as amended, the Resource Conservation and Recovery Act of 1976, as amended, the Safe Drinking Water Act, as amended, the Toxic Substances Control Act, as amended, the Superfund Amendments and Reauthorization Act of 1986, as amended, and the Hazardous Materials Transportation Law, as amended.

Environmental Permit” means any permit, registration, license, notice, approval, consent, exemption, variance, or other authorization required under or issued pursuant to any applicable Environmental Law.

Equity Interests” means shares of capital stock, partnership interests, membership interests in a limited liability company, beneficial interests in a trust or other equity ownership interests in a Person, and any warrants, options or other rights entitling the holder thereof to purchase or acquire any such Equity Interest.

ERISA” means the Employee Retirement Income Security Act of 1974, as amended from time to time, and the rules and regulations promulgated thereunder, and any successor statute.

ERISA Affiliate” means each trade or business (whether or not incorporated) which together with the Loan Parties would be deemed to be a “single employer” within the meaning of section 4001(b) (1) of ERISA or subsections (b), (c), (m) or (o) of section 414 of the Code.

ERISA Event” means any of the following: (a) a reportable event described in Section 4043(b) of ERISA (or, unless the 30-day notice requirement has been duly waived under the applicable regulations, Section 4043(c) of ERISA) with respect to a Plan; (b) the withdrawal of the Borrower, any Subsidiary or any ERISA Affiliate from a Plan subject to Section 4063 of ERISA during a plan year in which it was a substantial employer, as defined in Section 4001(a)(2) of ERISA; (c) the incurrence by the Borrower, any Subsidiary or any ERISA Affiliate of liability due to the

 

16


complete or partial withdrawal from any Multiemployer Plan; (d) with respect to any Multiemployer Plan, the receipt by the Borrower or any Subsidiary of a notice of insolvency or termination under Section 4041A of ERISA; (e) the receipt by the Borrower or any Subsidiary of a notice of intent to terminate a Plan under Section 4041 of ERISA; (f) the receipt by the Borrower or any Subsidiary of any notice of the institution of proceedings to terminate a Plan by the PBGC; (g) the failure by the Borrower or any Subsidiary or ERISA Affiliate to make by its due date any required contribution under Section 430(j) of the Code to any Plan; (h) the imposition of a Lien (other than an Excepted Lien) under Section 412 or 430(k) of the Code or Section 303 or 4068 of ERISA on any property (or rights to property, whether real or personal) of the Borrower or any Subsidiary.

Erroneous Payment” has the meaning assigned to such term in Section 11.15(a).

Erroneous Payment Return Deficiency” has the meaning assigned to such term in Section 11.15(d).

Erroneous Payment Subrogation Rights” has the meaning assigned to such term in Section 11.15(d).

EU Bail-In Legislation Schedule” means the document described as such and published by the Loan Market Association (or any successor person), as in effect from time to time.

Event of Default” has the meaning assigned to such term in Section 10.01.

Excepted Liens” means: (a) Liens for Taxes, assessments or other governmental charges or levies which are not delinquent or which are being contested in good faith by appropriate action and for which adequate reserves have been maintained in accordance with GAAP; (b) Liens in connection with workers’ compensation, unemployment insurance or other social security, old age pension or public liability obligations which are not delinquent or which are being contested in good faith by appropriate action and for which adequate reserves have been maintained in accordance with GAAP; (c) statutory landlord’s liens, operators’, vendors’, carriers’, warehousemen’s, repairmen’s, mechanics’, suppliers’, workers’, materialmen’s, construction or other like Liens arising by operation of law in the ordinary course of business or incident to the exploration, development, operation and maintenance of Oil and Gas Properties each of which is in respect of obligations that are not delinquent or which are being contested in good faith by appropriate action and for which adequate reserves have been maintained in accordance with GAAP; (d) contractual Liens which arise in the ordinary course of business under operating agreements, joint venture agreements, oil and gas partnership agreements, oil and gas leases, farm-out agreements, division orders, contracts for the sale, transportation or exchange of oil and natural gas, unitization and pooling declarations and agreements, area of mutual interest agreements, overriding royalty agreements, marketing agreements, processing agreements, net profits agreements, development agreements, service agreements, supply agreements, gas balancing or deferred production agreements, injection, repressuring and recycling agreements, fresh water supply agreements, salt water or other disposal agreements, seismic or other geophysical permits or agreements, and other agreements, in each case, which are usual and customary in the oil and gas business and are for claims which are not delinquent or which are being contested in good faith by appropriate action and for which adequate reserves have been maintained in accordance with

 

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GAAP; provided that any such Lien referred to in this clause does not materially impair the use of the Property covered by such Lien for the purposes for which such Property is held by Loan Parties or materially impair the value of such Property subject thereto; (e) Liens arising solely by virtue of any statutory or common law provision relating to banker’s liens, rights of set-off or similar rights and remedies and burdening only deposit accounts or other funds maintained with a creditor depository institution; provided that no such deposit account is a dedicated cash collateral account or is subject to restrictions against access by the depositor in excess of those set forth by regulations promulgated by the Board and no such deposit account is intended by the Loan Parties to provide collateral to the depository institution; (f) zoning and lead use requirements, easements, restrictions, servitudes, permits, conditions, covenants, exceptions or reservations in any Property of the Loan Parties for the purpose of roads, pipelines, transmission lines, transportation lines, distribution lines for the removal of gas, oil, coal or other minerals or timber, and other like purposes, or for the joint or common use of real estate, rights of way, facilities and equipment, that do not secure any monetary obligations and which in the aggregate do not materially impair the use of such Property for the purposes of which such Property is held by the Loan Parties or materially impair the value of such Property subject thereto; (g) Liens on cash or securities pledged to secure performance of tenders, surety and appeal bonds, government contracts, performance and return of money bonds, bids, trade contracts, leases, statutory obligations, regulatory obligations and other obligations of a like nature incurred in the ordinary course of business; (h) judgment and attachment Liens not giving rise to an Event of Default; provided that any appropriate legal proceedings which may have been duly initiated for the review of such judgment shall not have been finally terminated or the period within which such proceeding may be initiated shall not have expired and no action to enforce such Lien has been commenced (which has not been stayed); (i) Liens, titles and interests of lessors of personal Property leased by such lessors to the Loan Parties, restrictions and prohibitions on encumbrances and transferability with respect to such Property and the Loan Parties’ interests therein imposed by such leases, and Liens and encumbrances encumbering such lessors’ titles and interests in such Property and to which the Loan Parties’ leasehold interests may be subject or subordinate, in each case, whether or not evidenced by UCC financing statement filings or other documents of record; provided that such Liens do not secure Debt of the Loan Parties and do not encumber Property of Loan Parties other than the Property that is the subject of such leases; (j) liens, titles and interests of licensors of software and other intangible personal Property licensed by such licensors to the Loan Parties, restrictions and prohibitions on encumbrances and transferability with respect to such Property and the Loan Parties’ interests therein imposed by such licenses, and Liens and encumbrances encumbering such licensors’ titles and interests in such Property and to which the Loan Parties’ license interests may be subject or subordinate, in each case, whether or not evidenced by UCC financing statement filings or other documents of record and none of which interfere in any material respect with the business of the Loan Parties or materially detract from the value of the relevant assets of the Loan Parties; (k) Liens arising from UCC financing statement precautionary filings regarding operating leases entered into by the Loan Parties in the ordinary course of business covering the personal Property under lease; (l) Liens in favor of depository banks arising under documentation governing deposit accounts which Liens secure the payment of returned items, settlement item amounts, customary bank fees for maintaining deposit accounts and other related services, and similar items and fees; and (m) so long as Section 3 of the Callon Side Letter is in effect pursuant to the terms of Section 7 of the Callon Side Letter, any requirement that the Borrower or any of its Restricted Subsidiaries convey any Specified ORRI pursuant to the terms

 

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of the Callon Side Letter; provided, that (x) no intention to subordinate the first priority Lien granted in favor of the Administrative Agent and the Lenders is to be hereby implied or expressed by the permitted existence of such Excepted Liens and (y) in no event shall “Excepted Liens” secure Debt for borrowed money.

Excess Cash” means, at any time, the aggregate amount of cash, Cash Equivalents, marketable securities, treasury bonds and bills, certificates of deposit, investments in money market funds and commercial paper (other than Excluded Cash), in each case, held or owned by (whether directly or indirectly), credited to the account of, or otherwise reflected as an asset on the balance sheet of, the Loan Parties in excess of the greater of (a) $25 million and (b) 10% of the then effective Borrowing Base; provided, that prior to August 5, 2022 (as such date may be extended by the Administrative Agent in its sole discretion), Excess Cash shall exclude any such cash, Cash Equivalents, marketable securities, treasury bonds and bills, certificates of deposit, investments in money market funds or commercial paper, in each case, held in or credited to a Specified Bank Account).

Excess Cash Test Date” has the meaning assigned to such term in Section 3.04(c)(vi).

Exchange Act” shall mean the Securities Exchange Act of 1934, as amended, and the rules and regulations promulgated thereunder.

Excluded Accounts” means (a) each account all or substantially all of the deposits in which consist of amounts utilized to fund payroll, healthcare, employee benefit or tax obligations of the Loan Parties, (b) fiduciary accounts, trust accounts and escrow accounts that in each case are contractually obligated to be segregated from the other assets of any Loan Party for the benefit of unaffiliated third parties, (c) “zero balance” accounts or disbursement accounts and (d) other accounts so long as the average daily maximum balance in any such other account over any three Business Day period does not at any time exceed $1,000,000; provided that, the aggregate maximum balance for all such bank accounts excluded pursuant to this clause (e) on any day shall not exceed $2,500,000.

Excluded Cash” means (a) any cash of the Loan Parties allocated for, reserved or otherwise set aside to pay (i) amounts then due and owing to unaffiliated third parties for which any of the Loan Parties have issued (or will issue within five (5) Business Days) checks or have initiated (or will initiate within five (5) Business Days) wires or ACH transfers in order to pay such amounts or (ii) the reasonably estimated balance of the purchase price and closing costs anticipated to be paid to unaffiliated third parties in connection with a “sign and close” purchase and sale agreement or other acquisition agreement for which any of the Loan Parties have issued (or will issue within five (5) Business Days) checks or have initiated (or will initiate within five (5) Business Days) wires or ACH transfers in order to pay such amounts, (b) cash allocated for, reserved or otherwise set aside for and solely used for (i) payroll or employee benefit payment obligations, (ii) the payment of severance and ad valorem taxes and other taxes of any Loan Party, and (iii) royalty and working interest payments, vendor payments and suspense payments owing to third parties, (c) cash collateral accounts with respect to letters of credit, (d) any cash or cash equivalents of any Loan Party (1) held in escrow by an unaffiliated third party and constituting purchase price deposits and/or (2) held by any Loan Party constituting the reasonably estimated balance of the purchase price and closing costs, in each case held in connection with a pending acquisition from an

 

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unaffiliated third party reasonably projected to close within the next succeeding sixty (60) days pursuant to a binding and enforceable purchase and sale agreement, and (e) any cash or cash equivalents of any Loan Party held by any Loan Party constituting the reasonably estimated amount of any cash distributions with respect to the Parent’s Equity Interests that the Parent intends to make to holders of its Equity Interests, in each case which distributions are expressly permitted pursuant to Section 9.04(d) and which distributions shall be made within the next succeeding thirty (30) days.

Excluded Property” has the meaning assigned to such term in the Guarantee Agreement.

Excluded Swap Obligations” has the meaning assigned to such term in the Guarantee Agreement.

Excluded Taxes” means any of the following Taxes imposed on or with respect to a Recipient or required to be withheld or deducted from a payment to a Recipient: (a) Taxes imposed on or measured by net income (however denominated), franchise Taxes, and branch profits Taxes, in each case, (i) imposed as a result of such Recipient being organized under the laws of, or having its principal office or, in the case of any Lender, its applicable lending office located in, the jurisdiction imposing such Tax (or any political subdivision thereof) or (ii) that are Other Connection Taxes, (b) in the case of a Lender, U.S. federal withholding Taxes imposed on amounts payable to or for the account of such Lender with respect to an applicable interest in a Loan, Letter of Credit or Commitment pursuant to a law in effect on the date on which (i) such Lender acquires such interest in the Loan, Letter of Credit or Commitment (other than pursuant to an assignment request by the Borrower under Section 5.04) or (ii) such Lender changes its lending office, except in each case to the extent that, pursuant to Section 5.03, amounts with respect to such Taxes were payable either to such Lender’s assignor immediately before such Lender acquired the applicable interest in a Loan, Letter of Credit or Commitment or to such Lender immediately before it changed its lending office, (c) Taxes attributable to such Recipient’s failure to comply with Section 5.03(e), and (d) any U.S. federal withholding Taxes imposed under FATCA.

Existing Credit Agreement” has the meaning set forth in the recitals hereto.

Existing Lenders” has the meaning set forth in the recitals hereto.

Existing Loan Documents” has the meaning set forth in the recitals hereto.

Existing Loan Parties” has the meaning given to the term “Loan Parties” in the Existing Credit Agreement.

FATCA” means Sections 1471 through 1474 of the Code, as of the date of this Agreement (or any amended or successor version that is substantively comparable and not materially more onerous to comply with), any current or future regulations or official interpretations thereof, any agreement entered into pursuant to Section 1471(b)(1) of the Code and any fiscal or regulatory legislation, rules or practices adopted pursuant to any intergovernmental agreement, treaty or convention among Governmental Authorities and implementing such Sections of the Code.

Federal Funds Rate” means, for any day, the greater of (a) the rate per annum calculated by the Federal Reserve Bank of New York based on such day’s federal funds transactions by depository institutions (as determined in such manner as the Federal Reserve Bank of New York shall set

 

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forth on its public website from time to time) and published on the next succeeding Business Day by the Federal Reserve Bank of New York as the federal funds effective rate and (b) 0.00% per annum.

Fee Letters” means (a) that certain fee letter dated as of June 2, 2022, among KMF Land, the Administrative Agent and the Arranger and (b) any other letter agreements entered into from time to time after the Effective Date among the Borrower, on the one hand, and the Administrative Agent and/or the Arranger and/or any other arrangers or agents appointed after the Effective Date (with the consent of the Administrative Agent or its Affiliates), on the other hand, providing for the payment of fees to any such agent and/or arranger in connection with this Agreement or any transactions contemplated hereby.

Financial Officer” means, for any Person, the chief executive officer, chief financial officer, principal accounting officer, treasurer or controller or other natural person principally responsible for the financial matters of such Person (or in the case of any Person that is a partnership, of such Person’s general partner). Unless otherwise specified, all references herein to a Financial Officer means a Financial Officer of the Borrower.

Financial Statements” means the financial statement or statements referred to in Section 7.04(a).

Flood Insurance Regulations” means (a) the National Flood Insurance Act of 1968 as now or hereafter in effect or any successor statute thereto, (b) the Flood Disaster Protection Act of 1973 as now or hereafter in effect or any successor statute thereto, (c) the National Flood Insurance Reform Act of 1994 (amending 42 USC 4001, et seq.), as the same may be amended or recodified from time to time, (d) the Flood Insurance Reform Act of 2004 and any regulations promulgated thereunder and (e) the Biggert-Waters Flood Reform Act of 2012 and, in each case, any regulations promulgated thereunder.

Floor” means a rate of interest equal to 0.00% per annum.

Foreign Lender” means a Lender that is not a U.S. Person.

Foreign Subsidiary” means any Restricted Subsidiary that is not a Domestic Subsidiary.

Fronting Exposure” means, at any time there is a Defaulting Lender, with respect to the Issuing Bank, such Defaulting Lender’s LC Exposure other than LC Exposure as to which such Defaulting Lender’s participation obligation has been reallocated to other Lenders or cash collateralized in accordance with the terms hereof.

GAAP” means generally accepted accounting principles in the United States of America as in effect from time to time subject to the terms and conditions set forth in Section 1.05.

Governmental Authority” means the government of the United States of America, any other nation or any political subdivision thereof, whether state or local, and any agency, authority, instrumentality, regulatory body, court, central bank or other entity exercising executive, legislative, judicial, taxing, regulatory or administrative powers or functions of or pertaining to government.

 

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Governmental Requirement” means any law, statute, code, ordinance, order, determination, rule, regulation, judgment, decree, injunction, franchise, permit, certificate, license, rules of common law, authorization or other legally-binding determination, directive or requirement, whether now or hereafter in effect, of any Governmental Authority.

GP Pledgor” means Sitio Royalties GP, LLC, a Delaware limited liability company.

Guarantee Agreement” means the Second Amended and Restated Guarantee and Collateral Agreement executed by the GP Pledgor, Borrower and the Guarantors in substantially the form attached hereto as Exhibit F, as the same may be amended, restated, modified or supplemented from time to time.

Guarantors” means each Subsidiary that is a party to the Guarantee Agreement as a “Guarantor” and “Grantor” (as such terms are defined in the Guarantee Agreement) and guarantees the Obligations (including pursuant to Section 6.01 and Section 8.14(b)).

Hazardous Material” means any chemical, substance or waste designated or regulated as a “hazardous substance,” “hazardous material,” “hazardous waste,” “toxic waste,” “extremely hazardous substance,” “toxic substance,” “contaminant,” “pollutant,” or words of similar meaning or import under any applicable Environmental Law, including Hydrocarbons, petroleum products, petroleum substances, and any components, fractions, or derivatives thereof, and radioactive materials, explosives, asbestos or asbestos containing materials, polychlorinated biphenyls, and radon.

Highest Lawful Rate” means, with respect to each Lender, the maximum nonusurious interest rate, if any, that at any time or from time to time may be contracted for, taken, reserved, charged or received on the Notes or on other Obligations under laws applicable to such Lender which are presently in effect or, to the extent allowed by law, under such applicable laws which may hereafter be in effect and which allow a higher maximum nonusurious interest rate than applicable laws allow as of the date hereof.

Hydrocarbon Interests” means all rights, titles, interests and estates now or hereafter acquired in and to oil and gas leases, oil, gas and mineral leases, or other liquid or gaseous hydrocarbon leases, mineral fee interests, overriding royalty and royalty interests, net profit interests and production payment interests, including any reserved or residual interests of whatever nature. Unless otherwise indicated herein, each reference to the term “Hydrocarbon Interests” shall mean Hydrocarbon Interests of the Loan Parties, as the context requires.

Hydrocarbons” means oil, gas, casinghead gas, drip gasoline, natural gasoline, condensate, distillate, liquid hydrocarbons, gaseous hydrocarbons and all constituents, elements or compounds thereof and all products refined or separated therefrom and all other minerals which may be produced and saved from or attributable to the Oil and Gas Properties of any Person.

Immaterial Subsidiary” means any Restricted Subsidiary that is not a Material Subsidiary.

Indemnified Taxes” means (a) Taxes, other than Excluded Taxes, imposed on or with respect to any payment made by or on account of any obligation of the Borrower or any Guarantor under any Loan Document and (b) to the extent not otherwise described in clause (a) hereof, Other Taxes.

 

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Ineligible Institution” means (a) a natural person (or a holding company, investment vehicle or trust for, or owned and operated by or for the primary benefit of one or more natural persons), (b) a Defaulting Lender or its Lender Parent or (c) the Borrower or any of its Affiliates.

Information” has the meaning assigned to such term in Section 12.11.

Initial Reserve Report” means (a) the Reserve Report with respect to the New Loan Parties dated as of December 31, 2021 prepared by Approved Petroleum Engineers and delivered to the Administrative Agent; and (b) the Reserve Report with respect to the Existing Loan Parties dated as of December 31, 2021 prepared by Approved Petroleum Engineers and delivered to the Administrative Agent.

Interest Election Request” means a request by the Borrower to convert or continue a Borrowing substantially in the form of Exhibit C or otherwise acceptable to the Administrative Agent.

Interest Payment Date” means (a) with respect to any ABR Loan, the last day of each March, June, September and December and the Termination Date and (b) with respect to any Term SOFR Loan, the last day of each Interest Period applicable to such Loan and, in the case of a Term SOFR Loan with an Interest Period of more than three months’ duration, each day prior to the last day of such Interest Period that occurs at intervals of three months’ duration after the first day of such Interest Period, and the Termination Date.

Interest Period” means with respect to any Term SOFR Loan, the period commencing on the date such Loan is disbursed or converted to or continued as a Term SOFR Loan and ending on the numerically corresponding day in the calendar month that is one, three or six months thereafter, as the Borrower may elect; provided, that (i) if any Interest Period would end on a day other than a Business Day, such Interest Period shall be extended to the next succeeding Business Day unless such next succeeding Business Day would fall in the next calendar month, in which case such Interest Period shall end on the next preceding Business Day, (ii) any Interest Period pertaining to a Term SOFR Loan that commences on the last Business Day of a calendar month (or on a day for which there is no numerically corresponding day in the last calendar month of such Interest Period) shall end on the last Business Day of the last calendar month of such Interest Period and (iii) no Interest Period shall extend beyond the Maturity Date except in connection with an extension thereof permitted by this Agreement.

Interim Redetermination” has the meaning assigned to such term in Section 2.07(b).

Interim Redetermination Date” means the date on which a Borrowing Base that has been redetermined pursuant to an Interim Redetermination becomes effective as provided in Section 2.07(d).

Investment” means, for any Person: (a) the acquisition (whether for cash, Property, services or securities or otherwise) of Equity Interests of any other Person (including, without limitation, any “short sale” or any sale of any securities at a time when such securities are not owned by the Person entering into such short sale); (b) the making of any deposit with, or advance, loan or capital contribution to, assumption of Debt of, purchase or other acquisition of any other Debt or equity participation or interest in, or other extension of credit to, any other Person (including the purchase of Property from another Person subject to an understanding or agreement, contingent or

 

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otherwise, to resell such Property to such Person, but excluding any such advance, loan or extension of credit having a term not exceeding ninety (90) days representing the purchase price of inventory, goods, supplies or services sold by such Person in the ordinary course of business); (c) the purchase or acquisition (in one or a series of transactions) of Property of another Person that constitutes a business unit; or (d) the entering into of any guarantee of, or other contingent obligation (including the deposit of any Equity Interests to be sold) with respect to, Debt or other liability of any other Person and (without duplication) any amount committed to be advanced, lent or extended to such Person.

IRS” means the United States Internal Revenue Service.

ISP” means the International Standby Practices, International Chamber of Commerce Publication No. 590 (or such later version thereof as may be in effect at the applicable time).

Issuing Bank” means Bank of America, in its capacity as the issuer of Letters of Credit hereunder, and its successors in such capacity as provided in Section 2.08(i). The Issuing Bank may, in its discretion, arrange for one or more Letters of Credit to be issued by Affiliates of the Issuing Bank, in which case the term “Issuing Bank” shall include any such Affiliate with respect to Letters of Credit issued by such Affiliate.

KMF Land” has the meaning set forth in the preamble.

LC Commitment” means $15,000,000.

LC Disbursement” means a payment made by the Issuing Bank pursuant to a Letter of Credit.

LC Exposure” means, at any time, the sum of (a) the aggregate undrawn amount of all outstanding Letters of Credit at such time plus (b) the aggregate amount of all LC Disbursements that have not yet been reimbursed by or on behalf of the Borrower at such time. The LC Exposure of any Lender at any time shall be its Applicable Percentage of the LC Exposure at such time. For all purposes of this Agreement, if on any date of determination a Letter of Credit has expired by its terms but any amount may still be drawn thereunder by reason of the operation of Article 29(a) of the Uniform Customs and Practice for Documentary Credits, International Chamber of Commerce Publication No. 600 (or such later version thereof as may be in effect at the applicable time) or Rule 3.13 or Rule 3.14 of the International Standby Practices, International Chamber of Commerce Publication No. 590 (or such later version thereof as may be in effect at the applicable time) or similar terms of the Letter of Credit itself, or if compliant documents have been presented but not yet honored, such Letter of Credit shall be deemed to be “outstanding” and “undrawn” in the amount so remaining available to be paid, and the obligations of the Borrower and each Lender shall remain in full force and effect until the Issuing Bank and the Lenders shall have no further obligations to make any payments or disbursements under any circumstances with respect to any Letter of Credit.

Lender Parent” means, with respect to any Lender, any Person as to which such Lender is, directly or indirectly, a subsidiary.

 

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Lenders” means the Persons listed on Annex I and any other Person that shall have become a party hereto pursuant to an Assignment and Assumption or otherwise, other than any such Person that ceases to be a party hereto pursuant to an Assignment and Assumption.

Letter of Credit” means any letter of credit issued pursuant to this Agreement (including, for the avoidance of doubt, those letters of credit issued pursuant to the Existing Credit Agreement and deemed to be Letters of Credit issued pursuant to this Agreement pursuant to the operation of Section 2.08(b) and Section 12.23).

Letter of Credit Agreements” means all letter of credit applications and other agreements (including any amendments, modifications or supplements thereto) submitted by the Borrower, or entered into by the Borrower, with the Issuing Bank relating to any Letter of Credit.

Leverage Ratio” has the meaning assigned to such term in Section 9.01(a).

Lien” means any interest in Property securing an obligation owed to, or a claim by, a Person other than the owner of the Property, whether such interest is based on the common law, statute or contract, and whether such obligation or claim is fixed or contingent, and including but not limited to (a) the lien or security interest arising from a deed of trust, mortgage, encumbrance, pledge, security agreement, conditional sale or trust receipt or a lease, consignment or bailment for security purposes or (b) production payments and the like payable out of Oil and Gas Properties. The term “Lien” shall include easements, restrictions, servitudes, permits, conditions, covenants, exceptions or reservations that burden Property to the extent they secure an obligation owed to a Person other than the owner of the Property. For the purposes of this Agreement, a Loan Party shall be deemed to be the owner of any Property which it has acquired or holds subject to a conditional sale agreement, or leases under a financing lease or other arrangement pursuant to which title to the Property has been retained by or vested in some other Person in a transaction intended to create a financing. In no event shall the term “Lien” be deemed to include any license of intellectual property unless such license contains a grant of a security interest in such intellectual property.

Liquidate” means, with respect to any Swap Agreement, the sale, assignment, novation, unwind or early termination of all or any part of such Swap Agreement or the creation of an offsetting position against all or any part of such Swap Agreement. The terms “Liquidated” and “Liquidation” have correlative meanings thereto.

Liquidity” means, as of any date of determination, the sum of (a) the amount of the unused Commitments as of such date plus (b) the aggregate amount of Unrestricted Cash on such date, minus (c) the amount of any Borrowing Base Deficiency on such date.

Loan Documents” means this Agreement, the Notes, the Letter of Credit Agreements, the Letters of Credit, the Security Instruments, the Fee Letters, any certificate required to be delivered under this Agreement by or on behalf of any Loan Party, and any agreement executed by a Credit Party and any Loan Party which states that it is a “Loan Document” as defined herein.

Loan Parties” means, collectively, the Borrower and each Guarantor, and “Loan Party” means any one of the foregoing.

Loans” means the loans made by the Lenders to the Borrower pursuant to this Agreement.

 

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Majority Lenders” means, at any time while no Loans or LC Exposure is outstanding, Lenders having more than fifty percent (50.0%) of the Aggregate Maximum Credit Amounts; and at any time while any Loans or LC Exposure is outstanding, Lenders holding more than fifty percent (50.0%) of the outstanding aggregate principal amount of the Loans and participation interests in Letters of Credit (without regard to any sale by a Lender of a participation in any Loan under Section 12.04(c)); provided that the Maximum Credit Amounts and the principal amount of the Loans and participation interests in Letters of Credit of the Defaulting Lenders (if any) shall be excluded from the determination of Majority Lenders.

Material Acquisition” means any acquisition of Property or series of related acquisitions of Property that involves the payment of consideration by the Loan Parties in excess of the greater of (x) $15,000,000 and (y) 5.0% of the then-effective Borrowing Base.

Material Adverse Effect” means a material adverse change in, or material adverse effect on (a) the business, Property, operations or financial condition of the Loan Parties taken as a whole, (b) when taken as a whole, the ability of the Borrower or any Guarantor to perform any of its obligations under any Loan Document, (c) the validity or enforceability of any Loan Document or (d) the rights and remedies of the Administrative Agent, the Issuing Bank or any Lender under any Loan Document.

Material Debt” means Debt (other than the Loans and Letters of Credit), or obligations in respect of one or more Swap Agreements, of any one or more of the Loan Parties in an aggregate principal amount exceeding the greater of (x) $22,500,000 and (y) 7.5% of the then-effective Borrowing Base. For purposes of determining Material Debt, the “principal amount” of the obligations of the Loan Parties in respect of any Swap Agreement at any time shall be the Swap Termination Value of such Swap Agreement.

Material Disposition” means any Disposition of Property or series of related Dispositions of Property that yields gross proceeds to the Loan Parties (valued at the initial principal amount thereof in the case of non-cash proceeds consisting of notes or other debt securities and valued at fair market value in the case of other non-cash proceeds) in excess of the greater of (x) $15,000,000 and (y) 5.0% of the then-effective Borrowing Base.

Material Subsidiary” means, as of any date: (a) any Restricted Subsidiary that owns, or has an interest in, any Borrowing Base Property, as determined by the Administrative Agent; (b) any Restricted Subsidiary that incurs or guarantees any Debt for borrowed money (including any Permitted Additional Debt); and (c) any Restricted Subsidiary that is a Wholly-Owned Subsidiary and which, together with its subsidiaries that are Restricted Subsidiaries, as of the most recent fiscal quarter of the Borrower, for the period of four consecutive fiscal quarters (or, if applicable, the relevant annualized period determined in accordance with the definition of “EBITDA”) then ended for which financial statements have been delivered pursuant to Section 8.01(a) or Section 8.01(b) (or, if applicable, the Financial Statements), contributed greater than (i) five percent (5.0%) of EBITDA for such period or (ii) five percent (5.0%) of the Consolidated Total Assets as of the last day of such period; provided that, if at any time the aggregate amount of EBITDA or Consolidated Total Assets attributable to all Immaterial Subsidiaries, taken together, exceeds five percent (5%) of EBITDA for any such period or five percent (5%) of Consolidated Total Assets as of the end of any such fiscal quarter, then the Borrower shall designate in the compliance

 

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certificate required to be delivered pursuant to Section 8.01(c) for such fiscal quarter or fiscal year, as applicable, one or more Immaterial Subsidiaries as “Material Subsidiaries” to the extent necessary to eliminate such excess, and upon the delivery of such compliance certificate to the Administrative Agent, such designated Subsidiaries shall for all purposes of this Agreement constitute Material Subsidiaries, and the Borrower shall cause such designated Material Subsidiaries to comply with Section 8.14(b). In the event the Borrower fails to so designate sufficient additional Restricted Subsidiaries as “Material Subsidiaries” in the compliance certificate as aforesaid, the Administrative Agent may, by written notice to the Borrower, designate sufficient additional Restricted Subsidiaries as “Material Subsidiaries” on the Borrower’s behalf, whereupon such Restricted Subsidiaries, effective as of the date of such designation, shall constitute “Material Subsidiaries” for all purposes of this Agreement.

Maturity Date” means June 5, 2026.

Maximum Credit Amount” means, as to each Lender, the amount set forth opposite such Lender’s name on Annex I under the caption “Maximum Credit Amounts”, as the same may be (a) reduced or terminated from time to time in connection with a reduction or termination of the Aggregate Maximum Credit Amounts pursuant to Section 2.06(b), (b) modified from time to time pursuant to any assignment permitted by Section 12.04(b) or (c) modified from time to time pursuant to Section 2.06(c)(v).

Merger” has the meaning set forth in the recitals hereto.

Merger Agreement” means that certain Agreement and Plan of Merger, dated as of January 11, 2022, by and among Falcon Minerals Corporation, a Delaware corporation, Falcon Minerals Operating Partnership, LP, a Delaware limited partnership, Merger Sub and DPM Holdco, as amended, restated, supplemented or otherwise modified as permitted hereunder.

Merger Sub” has the meaning set forth in the recitals hereto.

Moody’s” means Moody’s Investors Service, Inc. and any successor thereto that is a nationally recognized rating agency.

Mortgaged Property” means any Property owned by the Borrower or any Guarantor which is subject to the Liens existing and to exist under the terms of the Security Instruments.

Multiemployer Plan” means any multiemployer plan, as defined in Section 3(37) or 4001(a)(3) of ERISA, which (a) is currently or hereafter contributed to by the Borrower, a Subsidiary or an ERISA Affiliate or (b) was at any time during the six calendar years preceding the date hereof contributed to by the Borrower, a Subsidiary or an ERISA Affiliate.

New Borrowing Base Notice” has the meaning assigned to such term in Section 2.07(d).

New Loan Parties” means the Borrower and its Subsidiaries other than the Existing Loan Parties.

Non-Consenting Lender” means any Lender that fails to consent to an amendment, waiver, consent or other modification to this Agreement or any other Loan Document requested by the Borrower (excluding, for the avoidance of doubt, any Borrowing Base increase) that requires the

 

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consent of all Lenders or all affected Lenders in accordance with the terms of Section 12.02(b), and such amendment, waiver, consent or other modification is otherwise consented to by the Required Lenders.

Non-Defaulting Lender” means, at any time, each Lender that is not a Defaulting Lender at such time.

Notes” means the promissory notes of the Borrower described in Section 2.02(d) and being substantially in the form of Exhibit A, together with all amendments, modifications, replacements, extensions and rearrangements thereof.

Obligations” means (a) any and all amounts owing or to be owing by the Borrower or any Guarantor (whether direct or indirect (including those acquired by assumption), absolute or contingent, due or to become due, now existing or hereafter arising) to the Administrative Agent, the Arranger, the Issuing Bank, any Lender or any Related Party of any of the foregoing under any Loan Document; (b) all Secured Swap Obligations; (c) all Secured Cash Management Obligations; and (d) all renewals, extensions and/or rearrangements of any of the above. Without limitation of the foregoing, the term “Obligations” shall include the unpaid principal of and interest on the Loans and LC Exposure (including, without limitation, interest accruing at the then applicable rate provided in this Agreement after the maturity of the Loans and LC Exposure and interest accruing at the then applicable rate provided in this Agreement after the filing of any petition in bankruptcy, or the commencement of any insolvency, reorganization or like proceeding, relating to the Borrower or any Guarantor, whether or not a claim for post-filing or post-petition interest is allowed in such proceeding), reimbursement obligations (including, without limitation, to reimburse LC Disbursements), obligations to post cash collateral in respect of, or otherwise backstop, Letters of Credit, payments in respect of an early termination of Secured Swap Obligations and unpaid amounts, fees, expenses, indemnities, costs, and all other obligations and liabilities of every nature of the Loan Parties, whether absolute or contingent, due or to become due, now existing or hereafter arising under this Agreement, the other Loan Documents, any Secured Swap Agreement or any Secured Cash Management Agreement.

OFAC” means the U.S. Department of the Treasury Office of Foreign Assets Control.

Oil and Gas Properties” means (a) Hydrocarbon Interests; (b) the Properties now or hereafter pooled or unitized with Hydrocarbon Interests; (c) all presently existing or future unitization agreements, communitization agreements, pooling agreements and declarations of pooled units and the units created thereby (including without limitation all units created under orders, regulations and rules of any Governmental Authority) which may affect all or any portion of the Hydrocarbon Interests; (d) all operating agreements, contracts and other agreements, including production sharing contracts and agreements, which relate to any of the Hydrocarbon Interests or the production, sale, purchase, exchange or processing of Hydrocarbons from or attributable to such Hydrocarbon Interests; (e) all Hydrocarbons in and under and which may be produced and saved or attributable to the Hydrocarbon Interests, including all oil in tanks, and all rents, issues, profits, proceeds, products, revenues and other incomes from or attributable to the Hydrocarbon Interests; (f) all tenements, hereditaments, appurtenances and Properties in any manner appertaining, belonging, affixed or incidental to the Hydrocarbon Interests and (g) all Properties, rights, titles, interests and estates described or referred to above, including any and all Property,

 

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real or personal, now owned or hereinafter acquired and situated upon, used, held for use or useful in connection with the operating, working or development of any of such Hydrocarbon Interests or Property (excluding drilling rigs, automotive equipment, rental equipment or other personal Property which may be on such premises for the purpose of drilling a well or for other similar temporary uses) and including any and all oil wells, gas wells, injection wells or other wells, structures, fuel separators, liquid extraction plants, plant compressors, pumps, pumping units, field gathering systems, tanks and tank batteries, fixtures, valves, fittings, machinery and parts, engines, boilers, meters, apparatus, equipment, appliances, tools, implements, cables, wires, towers, casing, tubing and rods, surface leases, rights-of-way, easements and servitudes together with all additions, substitutions, replacements, accessions and attachments to any and all of the foregoing. Unless otherwise indicated herein, each reference to the term “Oil and Gas Properties” shall mean Oil and Gas Properties with respect to which a Loan Party, as the context requires, has any right, title or interest.

Other Connection Taxes” means, with respect to any Recipient, Taxes imposed as a result of a present or former connection between such Recipient and the jurisdiction imposing such Tax (other than connections arising from such Recipient having executed, delivered, become a party to, performed its obligations under, received payments under, received or perfected a security interest under, engaged in any other transaction pursuant to or enforced any Loan Document, or sold or assigned an interest in any Loan, Letter of Credit or Loan Document).

Other Taxes” means all present or future stamp, court or documentary, intangible, recording, filing or similar Taxes that arise from any payment made under, from the execution, delivery, performance, enforcement or registration of, from the receipt or perfection of a security interest under, or otherwise with respect to, any Loan Document, except any such Taxes that are Other Connection Taxes imposed with respect to an assignment (other than an assignment made pursuant to Section 5.04).

Parent” means Sitio Royalties Corp., a Delaware corporation.

Participant” has the meaning set forth in Section 12.04(c).

Participant Register” has the meaning set forth in Section 12.04(c).

Payment in Full” means (a) the Commitments have expired or have been terminated, (b) all Obligations (including, without limitation, all principal, interest (including interest accruing during the pendency of an insolvency or liquidation proceeding, regardless of whether allowed or allowable in such insolvency or liquidation proceeding), and all fees, costs, expenses and other amounts payable under this Agreement and the other Loan Documents) shall have been paid in full in cash (other than inchoate or contingent indemnification obligations, Secured Swap Obligations and Secured Cash Management Obligations), and (c) all Letters of Credit shall have expired or terminated, without any pending draw (or are cash collateralized or otherwise backstopped in such amounts and pursuant to such arrangements as are satisfactory to the Issuing Bank in its sole discretion) and all LC Disbursements shall have been reimbursed.

Payment Recipient” has the meaning set forth in Section 11.15(a).

PBGC” means the Pension Benefit Guaranty Corporation as defined in Title IV of ERISA.

 

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Permitted Additional Debt” means unsecured senior notes or unsecured senior subordinated notes incurred by the Borrower after the Effective Date under Section 9.02(g).

Permitted Additional Debt Documents” means any credit agreement, notes, indenture, agreement, instrument or other definitive document governing, evidencing or related to, or securing, guaranteeing or otherwise providing credit support for, any Permitted Additional Debt, as the same may be amended, modified or supplemented to the extent permitted by Section 9.21.

Permitted Holders” means, collectively, (a) The Blackstone Group, Inc., (b) Oaktree Capital Management, L.P., (c) Kimmeridge Energy Management Company, LLC, (d) Kimmeridge Mineral Fund, LP, and (e) trusts, partnerships, limited liability companies, corporations or other entities that are Controlled by one or more Persons in the foregoing clauses (a), (b), (c) and (d) and.

Permitted Tax Distributions” means, (a) for any taxable period (or portion thereof) for which the Loan Parties are members of a consolidated, combined, unitary or similar income or franchise tax group for U.S. federal or applicable state or local income or franchise tax purposes of which the direct or indirect parent company of the Parent is the common parent (a “Tax Group”) or for which the Parent is a partnership or disregarded entity for U.S. federal or applicable state or local income or franchise tax purposes in any applicable taxing jurisdiction that is wholly-owned (directly or indirectly) by an entity that is taxable as a corporation for such income or franchise tax purposes, cash distributions to pay the portion of any U.S. federal, state or local income or franchise taxes (as applicable) of such Tax Group or such parent company for such taxable period that are attributable to the net taxable income of the Loan Parties (and, to the extent permitted below, the applicable Unrestricted Subsidiaries); provided, that a distribution under this clause shall not exceed the amount of Taxes that the Loan Parties would have paid as a single corporation or as a stand-alone Tax Group, and (b) without duplication of amounts payable under clause (a), with respect to any taxable period during which the Borrower is a partnership for U.S. federal income tax purposes, or is disregarded as separate from an entity classified as a partnership for United States federal income tax purposes, cash distributions to the holders of its Equity Interests, on or prior to each estimated tax payment date as well as each other applicable due date, in an amount sufficient to permit the holders of such Equity Interests (or their direct or indirect owners) to meet their tax distribution obligations under the applicable governing documents attached to the certificate delivered pursuant to Section 6.01(b)(iv); provided, that, notwithstanding the foregoing, distributions or dividends under this definition in respect of an Unrestricted Subsidiary shall be permitted only to the extent that cash distributions were made by such Unrestricted Subsidiary to the Borrower or any of its Restricted Subsidiaries for such purpose.

Person” means any natural person, corporation, limited liability company, trust, joint venture, association, company, partnership, Governmental Authority or other entity.

Plan” means any employee pension benefit plan, as defined in section 3(2) of ERISA subject to Section 412 of the Code or Section 302 or Title IV of ERISA (other than a Multiemployer Plan), which (a) is currently or hereafter sponsored, maintained or contributed to by the Loan Parties or an ERISA Affiliate or (b) was at any time during the six calendar years preceding the date hereof, sponsored, maintained or contributed to by the Loan Parties or an ERISA Affiliate.

 

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Prime Rate” means a rate set by Bank of America based upon various factors including Bank of America’s costs and desired return, general economic conditions and other factors, and is used as a reference point for pricing some loans, which may be priced at, above, or below such announced rate. Any change in such rate announced by Bank of America shall take effect at the opening of business on the day specified in the public announcement of such change.

Property” means any interest in any kind of property or asset, whether real, personal or mixed, or tangible or intangible, including, without limitation, cash, securities, accounts and contract rights.

Proposed Borrowing Base” has the meaning assigned to such term in Section 2.07(c)(i).

Proposed Borrowing Base Notice” has the meaning assigned to such term in Section 2.07(c)(ii).

PTE” means a prohibited transaction class exemption issued by the U.S. Department of Labor, as any such exemption may be amended from time to time.

Public Company Compliance” means compliance with the requirements of the Sarbanes-Oxley Act of 2002 and the rules and regulations promulgated in connection therewith, the provisions of the Securities Act and the Exchange Act, and the rules of national securities exchange listed companies (in each case, as applicable to companies with equity or debt securities held by the public), including procuring directors’ and officers’ insurance, legal and other professional fees, and listing fees.

QFC” has the meaning assigned to the term “qualified financial contract” in, and shall be interpreted in accordance with, 12 U.S.C. 5390(c)(8)(D).

QFC Credit Support” has the meaning assigned to such term in Section 12.20.

Qualified ECP Counterparty” means, in respect of any Swap Agreement, the Borrower and each Restricted Subsidiary and each Guarantor that (a) has total assets exceeding $10,000,000 at the time any guarantee of obligations under such Swap Agreement or grant of the relevant security interest to secure such Swap Agreement becomes effective or (b) otherwise constitutes an “eligible contract participant” under the Commodity Exchange Act and can cause another Person to qualify as an “eligible contract participant” at such time by entering into a keepwell under Section 1a(18)(A)(v)(II) of the Commodity Exchange Act.

Recipient” means (a) the Administrative Agent, (b) any Lender and (c) the Issuing Bank, as applicable.

Redemption” means with respect to any Debt, the repurchase, redemption, prepayment, repayment, defeasance or any other acquisition or retirement for value (or the segregation of funds with respect to any of the foregoing) of such Debt. “Redeem” and “Redeemed” have correlative meanings thereto.

Redetermination Date” means, with respect to any Scheduled Redetermination or any Interim Redetermination, the date that the redetermined Borrowing Base related thereto becomes effective pursuant to Section 2.07(d).

 

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Reference Period” has the meaning assigned to such term in the definition of EBITDA.

Register” has the meaning assigned to such term in Section 12.04(b)(iv).

Regulation D” means Regulation D of the Board, as in effect from time to time and all official rulings and interpretations thereunder or thereof.

Related Parties” means, with respect to any specified Person, such Person’s Affiliates and the directors, officers, employees, agents and professional advisors (including attorneys, accountants and experts) of such Person and of such Person’s Affiliates.

Release” means any depositing, spilling, leaking, pumping, pouring, placing, emitting, discarding, abandoning, emptying, discharging, migrating, injecting, escaping, leaching, dumping, or disposing. “Released” has a meaning correlative thereto.

Release Date” means the date on which (i) Payment in Full has occurred, (ii) no Secured Swap Agreement is outstanding and all amounts payable by the Loan Parties to any Secured Swap Party under any Secured Swap Agreement shall have been paid in full, or if any Secured Swap Agreement is outstanding, arrangements acceptable in the sole discretion of the Secured Swap Party thereto have been made, or such Secured Swap Agreement has been novated or assigned to one or more third parties and all amounts required to be paid by the Loan Parties in respect of such novation shall have been paid in full and (iii) the payment in full in cash of all amounts owing under and the termination of all Secured Cash Management Obligations has occurred (other than contingent indemnification obligations and Secured Cash Management Obligations as to which arrangements satisfactory to the applicable Secured Cash Management Provider shall have been made).

Relevant Governmental Body” means the Board or the Federal Reserve Bank of New York, or a committee officially endorsed or convened by the Board or the Federal Reserve Bank of New York, or any successor thereto.

Required Lenders” means, at any time while no Loans or LC Exposure is outstanding, Lenders having at least sixty-six and two-thirds percent (66-2/3%) of the Aggregate Maximum Credit Amounts of all Lenders; and at any time while any Loans or LC Exposure is outstanding, Lenders holding at least sixty-six and two-thirds percent (66-2/3%) of the outstanding aggregate principal amount of the Loans and participation interests in Letters of Credit of all Lenders (without regard to any sale by a Lender of a participation in any Loan under Section 12.04(c)); provided that the Maximum Credit Amounts and the principal amount of the Loans and participation interests in Letters of Credit of the Defaulting Lenders (if any) shall be excluded from the determination of Required Lenders.

Reserve Report” means the Initial Reserve Report and any other subsequent report, in form and substance reasonably satisfactory to the Administrative Agent, setting forth, as of each January 1st or July 1st (or such other date as may be acceptable to the Administrative Agent in its sole discretion or as applicable in the event of an Interim Redetermination) the oil and gas reserves attributable to the Oil and Gas Properties of the Loan Parties, together with a projection of the rate of production and future net income, Taxes, operating expenses and capital expenditures with respect thereto as of such date, based upon the pricing assumptions consistent with the Administrative Agent’s lending requirements at the time.

 

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Resolution Authority” means an EEA Resolution Authority or, with respect to any UK Financial Institution, a UK Resolution Authority.

Responsible Officer” means, as to any Person, the Chief Executive Officer, the President, the General Counsel, any Financial Officer or any Vice President of such Person or of such Person’s manager, managing member, general partner or such other Person having authority to bind that Person (or in the case of any Person that is a partnership, of such Person’s general partner). Unless otherwise specified, all references to a Responsible Officer herein means a Responsible Officer of the Borrower.

Restricted Payment” means any dividend or other distribution (whether in cash, securities or other Property) with respect to any Equity Interests in the Loan Parties, or any payment (whether in cash, securities or other Property), including any sinking fund or similar deposit, on account of the purchase, redemption, retirement, acquisition, cancellation or termination of any such Equity Interests in the Loan Parties or any option, warrant or other right to acquire any such Equity Interests in the Loan Parties.

Restricted Subsidiary” means any Subsidiary of the Borrower that is not an Unrestricted Subsidiary.

Revolving Credit Exposure” means, with respect to any Lender at any time, the sum of the outstanding principal amount of such Lender’s Loans and its LC Exposure at such time.

S&P” means Standard & Poor’s Rating Services, a Standard & Poor’s Financial Services LLC business, and any successor thereto that is a nationally recognized rating agency.

Sanctioned Country” means, at any time, a country, region or territory which is itself the subject or target of any Sanctions (at the time of this Agreement, the so-called Donetsk People’s Republic (DNR) region of Ukraine, the so-called Luhansk People’s Republic (LNR) region of Ukraine, the Crimea region of Ukraine, Cuba, Iran, North Korea and Syria).

Sanctioned Person” means, at any time, (a) any Person listed in any Sanctions-related list of designated Persons maintained by OFAC, the U.S. Department of State, the United Nations Security Council, the European Union, any European Union member state, Her Majesty’s Treasury of the United Kingdom or other relevant sanctions authority, (b) any Person operating, organized or resident in a Sanctioned Country or (c) any Person owned or controlled by any such Person or Persons described in the foregoing clauses (a) or (b).

Sanctions” means all economic or financial sanctions or trade embargoes imposed, administered or enforced from time to time by (a) the U.S. government, including those administered by OFAC or the U.S. Department of State or (b) the United Nations Security Council, the European Union, any European Union member state, Her Majesty’s Treasury of the United Kingdom or other relevant sanctions authority.

Scheduled Redetermination” has the meaning assigned to such term in Section 2.07(b).

 

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Scheduled Redetermination Date” means the date on which a Borrowing Base that has been redetermined pursuant to a Scheduled Redetermination becomes effective as provided in Section 2.07(d).

Scheduled Unavailability Date” has the meaning assigned to such term in Section 3.03(b).

SEC” means the Securities and Exchange Commission of the United States of America or any successor Governmental Authority.

Secured Cash Management Agreement” means a Cash Management Agreement between (a) any Loan Party and (b) a Secured Cash Management Provider.

Secured Cash Management Obligations” means any and all amounts and other obligations owing by any Loan Party to any Secured Cash Management Provider under any Secured Cash Management Agreement.

Secured Cash Management Provider” means, with respect to any Secured Cash Management Agreement, a Lender, an Affiliate of a Lender, the Administrative Agent or an Affiliate of the Administrative Agent who is the counterparty to any such Secured Cash Management Agreement.

Secured Parties” means the Administrative Agent, each Lender, the Issuing Bank, each Secured Cash Management Provider and each Secured Swap Party, and “Secured Party” shall mean any one of them.

Secured Swap Agreement” means any Swap Agreement between any Loan Party and any Person that is entered into prior to the time, or during the time, that such Person was, a Lender or an Affiliate of a Lender (including any such Swap Agreement in existence prior to the date hereof), even if such Person subsequently ceases to be a Lender (or an Affiliate of a Lender) for any reason (any such Person, a “Secured Swap Party”); provided that, the term “Secured Swap Agreement” shall not include any Swap Agreement or transactions under any Swap Agreement entered into after the time that such Secured Swap Party ceases to be a Lender or an Affiliate of a Lender.

Secured Swap Obligations” means all amounts and other obligations, owing to any Secured Swap Party under any Secured Swap Agreement (other than Excluded Swap Obligations).

Secured Swap Party” has the meaning assigned to such term in the definition of Secured Swap Agreement.

Securities Account” has the meaning assigned to such term in the UCC.

Securities Act” shall mean the Securities Act of 1933, as amended, and the rules and regulations promulgated thereunder.

Security Instruments” means the Guarantee Agreement, mortgages, deeds of trust, Control Agreements and other agreements, instruments or certificates described or referred to in Exhibit E, and any and all other agreements, instruments, consents or certificates now or hereafter executed and delivered by the Borrower or any other Person (other than Secured Swap Agreements or participation or similar agreements between any Lender and any other lender or creditor with

 

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respect to any Obligations pursuant to this Agreement), in each case in connection with, or as security for the payment or performance of the Obligations, the Notes, this Agreement, or reimbursement obligations under the Letters of Credit, as such agreements may be amended, modified, supplemented or restated from time to time.

SOFR” means a rate equal to the secured overnight financing rate as administered by the SOFR Administrator.

SOFR Adjustment” means (a) with respect to Daily Simple SOFR, 0.10% (10 basis points); and (b) with respect to Term SOFR, 0.10% (10 basis points) for an Interest Period of one-month’s duration, 0.15% (15 basis points) for an Interest Period of three-month’s duration, and 0.25% (25 basis points) for an Interest Period of six-months’ duration.

SOFR Administrator” means the Federal Reserve Bank of New York or a successor administrator of the secured overnight financing right.

Specified Bank Accounts” has the meaning set forth in Section 8.17(a).

Specified Equity Contribution” means, an amount equal to, without duplication, the amount of any capital contributions made in cash to, or any cash proceeds of an issuance of Equity Interests of the Borrower (other than Disqualified Capital Stock) received by, the Borrower during the applicable Cure Period that are made for the purpose of exercising the equity cure rights set forth in Section 9.01(c). For the avoidance of doubt, any capital contributions made to, or any cash proceeds of an issuance of Equity Interests of the Borrower received by, the Borrower for the purpose of making Investments pursuant to Section 9.05(m) shall not constitute a Specified Equity Contribution.

Specified ORRI” means, collectively, (a) the “Assets” as defined in the Specified ORRI Assignment, (b) the “Assigned Rights and Obligations” as defined in the Callon Side Letter Assignment and (c) any Oil and Gas Properties received in exchange for or in replacement of the Assets described in clause (a) or Oil and Gas Properties described in this clause (c) in each case, pursuant to the terms of the Callon Side Letter.

Specified ORRI Assignment” means that certain Conveyance of Overriding Royalty Interest effective as of June 30, 2021, by and among Chambers DE Minerals, LLC, a Delaware limited company, KMF Land, and Desert ORRI, LP, a Texas limited partnership.

subsidiary” means, with respect to any Person (the “parent”) at any date, any other Person the accounts of which would be consolidated with those of the parent in the parent’s consolidated financial statements if such financial statements were prepared in accordance with GAAP as of such date, as well as any other Person (a) of which Equity Interests representing more than 50% of the equity or more than 50% of the ordinary voting power (irrespective of whether or not at the time Equity Interests of any other class or classes of such Person shall have or might have voting power by reason of the happening of any contingency) or, in the case of a partnership, any general partnership interests are, as of such date, owned, controlled or held, or (b) that is, as of such date, otherwise Controlled, by the parent or one or more subsidiaries of the parent or by the parent and one or more subsidiaries of the parent.

 

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Subsidiary” means any subsidiary of the Borrower.

Successor Rate” has the meaning specified in Section 3.03(b).

Supported QFC” has the meaning assigned to such term in Section 12.20.

Swap Agreement” means any agreement with respect to any swap, forward, future or derivative transaction or option or similar agreement, whether exchange traded, “over-the-counter” or otherwise, involving, or settled by reference to, one or more rates, currencies, commodities, equity or debt instruments or securities, or economic, financial or pricing indices or measures of economic, financial or pricing risk or value or any similar transaction or any combination of these transactions; provided that no phantom stock or similar plan providing for payments only on account of services provided by current or former directors, officers, employees or consultants of any Loan Party (or of the manager, managing member, general partner or such other Person having authority to bind any Loan Party) shall be a Swap Agreement.

Swap Termination Value” means, in respect of any one or more Swap Agreements, after taking into account the effect of any legally enforceable netting agreement relating to such Swap Agreements, (a) for any date on or after the date such Swap Agreements have been closed out and termination value(s) determined in accordance therewith, such termination value(s) payable by any Loan Party, and (b) for any date prior to the date referenced in clause (a), the amount(s) determined as the mark-to-market value(s) for such Swap Agreements, with respect to which any Loan Party is “out-of-the-money”, as determined by the counterparties to such Swap Agreements (including, without duplication, any unpaid amounts due on the date of calculation).

Synthetic Leases” means, in respect of any Person, all synthetic leases, tax retention operating leases, off balance sheet loans or similar off balance sheet financing products where such transactions are considered borrowed money indebtedness for tax purposes which shall have been, or should have been, in accordance with GAAP, treated as operating leases on the financial statements of the Person liable (whether contingently or otherwise) for the payment of rent thereunder and which were properly treated as indebtedness for borrowed money for purposes of U.S. federal income Taxes.

Taxes” means all present or future taxes, levies, imposts, duties, deductions, charges or, withholdings (including backup withholding), value added taxes, or any other goods and services, use or sales taxes, assessments, fees or other charges imposed by any Governmental Authority including any interest, additions to tax or penalties applicable thereto.

Term SOFR” means,

(a)    for any Interest Period with respect to a Term SOFR Loan, the rate per annum equal to the Term SOFR Screen Rate two U.S. Government Securities Business Days prior to the commencement of such Interest Period with term equivalent to such Interest Period; provided that if the rate is not published prior to 11:00 a.m. on such determination date then Term SOFR means the Term SOFR Screen Rate on the first U.S. Government Securities Business Day immediately prior thereto, in each case, plus the SOFR Adjustment for such Interest Period; and

 

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(b)    for any interest calculation with respect to an ABR Loan on any date, the rate per annum equal to the Term SOFR Screen Rate with a term of one month commencing that day;

provided that if the Term SOFR determined in accordance with either of the foregoing provisions (a) or (b) of this definition would otherwise be less than zero, the Term SOFR shall be deemed zero for purposes of this Agreement.

Term SOFR Borrowing” means any Borrowing comprised of Term SOFR Loans.

Term SOFR Loan” means a Loan that bears interest at a rate based on clause (a) of the definition of Term SOFR.

Term SOFR Replacement Date” has the meaning assigned to such term in Section 3.03(b).

Term SOFR Screen Rate” means the forward-looking SOFR term rate administered by CME (or any successor administrator satisfactory to the Administrative Agent) and published on the applicable Reuters screen page (or such other commercially available source providing such quotations as may be designated by the Administrative Agent from time to time).

Termination Date” means the earlier of the Maturity Date and the date of termination of the Commitments.

Total Debt” means, at any date, all Debt of the Loan Parties on a consolidated basis, excluding (i) non-cash obligations under FASB ASC 815 and (ii) Debt in respect of clause (b) under the definition thereof.

Total Net Debt” means, at any date, an amount equal to (a) Total Debt minus (b) Unrestricted Cash in an aggregate amount not to exceed $25,000,000.

Transactions” means, (i) the consummation of the Merger and the other transactions occurring under the Merger Agreement on or about the Effective Date, (ii) the Effective Date Refinancing, (iii) (a) the execution, delivery and performance by the Borrower of this Agreement and each other Loan Document to which it is a party, the borrowing of Loans, the use of the proceeds thereof and the issuance of Letters of Credit hereunder, and the grant of Liens by the Borrower on Mortgaged Properties and other Properties pursuant to the Security Instruments, (b) the execution, delivery and performance by each Guarantor of each Loan Document to which it is a party, the guaranteeing of the Obligations and the other obligations under the Guarantee Agreement by such Guarantor, and the grant of Liens by such Guarantor on Mortgaged Properties and other Properties pursuant to the Security Instruments and (c) the execution, delivery and performance by the GP Pledgor of the Guarantee Agreement and the limited recourse grant of Liens by the GP Pledgor on its general partner interests in the Borrower and certain applicable Guarantors and (iv) the payment of fees, costs and expenses in connection with the foregoing.

Type”, when used in reference to any Loan, refers to its character as an ABR Loan or a Term SOFR Loan.

 

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UCC” means the Uniform Commercial Code as in effect from time to time in the State of New York.

UCP” means the Uniform Customs and Practice for Documentary Credits, International Chamber of Commerce Publication No. 600 (or such later version thereof as may be in effect at the applicable time).

UK Financial Institution” means any BRRD Undertaking (as such term is defined under the PRA Rulebook (as amended from time to time) promulgated by the United Kingdom Prudential Regulation Authority) or any Person subject to IFPRU 11.6 of the FCA Handbook (as amended from time to time) promulgated by the United Kingdom Financial Conduct Authority, which includes certain credit institutions and investment firms, and certain affiliates of such credit institutions or investment firms.

UK Resolution Authority” means the Bank of England or any other public administrative authority having responsibility for the resolution of any UK Financial Institution.

Unrestricted Cash” means cash or Cash Equivalents of the Borrower or any of the Guarantors that is held in Deposit Accounts and/or Securities Accounts subject to a Control Agreement.

Unrestricted Subsidiary” means any Subsidiary of the Borrower designated by the Borrower as an Unrestricted Subsidiary after the Effective Date in accordance with, and subject to the satisfaction of the conditions set forth in, Section 1.07.

U.S. Government Securities Business Day” means any day except for (a) a Saturday, (b) a Sunday or (c) a day on which the Securities Industry and Financial Markets Association, the New York Stock Exchange or the Federal Reserve Bank of New York is not open for business because such day is a legal holiday under the federal laws of the United States or the laws of the State of New York, as applicable.

U.S. Person” means a “United States person” within the meaning of Section 7701(a)(30) of the Code.

U.S. Special Resolution Regimes” has the meaning assigned to such term in Section 12.20.

U.S. Tax Compliance Certificate” has the meaning assigned to such term in Section 5.03(e)(ii)(B)(3).

USA PATRIOT Act” means the Uniting and Strengthening America by Providing Appropriate Tools Required to Intercept and Obstruct Terrorism Act of 2001 (Title III of Pub. L. 107-56), as amended.

Wholly-Owned Subsidiary” means any Restricted Subsidiary of which all of the outstanding Equity Interests (other than any directors’ qualifying shares mandated by applicable law), on a fully-diluted basis, are owned by the Borrower or one or more of the Wholly-Owned Subsidiaries of the Borrower or are owned by the Borrower and one or more of the Wholly-Owned Subsidiaries of the Borrower; provided that any Restricted Subsidiary which is a limited partnership of which all of the outstanding Equity Interests (other than any directors’ qualifying shares mandated by

 

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applicable law) which are limited partner interests, on a fully-diluted basis, are owned by the Borrower or one or more of the Wholly-Owned Subsidiaries of the Borrower or are owned by the Borrower and one or more of the Wholly-Owned Subsidiaries of the Borrower shall be deemed to be a Wholly-Owned Subsidiary notwithstanding that the Equity Interests which are general partner interests are owned by the GP Pledgor.

Write-Down and Conversion Powers” means, (a) with respect to any EEA Resolution Authority, the write-down and conversion powers of such EEA Resolution Authority from time to time under the Bail-In Legislation for the applicable EEA Member Country, which write-down and conversion powers are described in the EU Bail-In Legislation Schedule, and (b) with respect to the United Kingdom, any powers of the applicable Resolution Authority under the Bail-In Legislation to cancel, reduce, modify or change the form of a liability of any UK Financial Institution or any contract or instrument under which that liability arises, to convert all or part of that liability into shares, securities or obligations of that Person or any other Person, to provide that any such contract or instrument is to have effect as if a right had been exercised under it or to suspend any obligation in respect of that liability or any of the powers under that Bail-In Legislation that are related to or ancillary to any of those powers.

Section 1.03    Rounding. Any financial ratios required to be maintained by the Borrower pursuant to this Agreement shall be calculated by dividing the appropriate component by the other component, carrying the result to one place more than the number of places by which such ratio is expressed herein and rounding the result up or down to the nearest number (with a rounding-up if there is no nearest number).

Section 1.04    Terms Generally; Rules of Construction. With reference to this Agreement and each other Loan Document, unless otherwise specified herein or in such other Loan Document:

The definitions of terms herein shall apply equally to the singular and plural forms of the terms defined. Whenever the context may require, any pronoun shall include the corresponding masculine, feminine and neuter forms. The words “include”, “includes” and “including” shall be deemed to be followed by the phrase “without limitation”, and the word “or” shall not be exclusive. The word “will” shall be construed to have the same meaning and effect as the word “shall”. Unless the context requires otherwise (i) any definition of or reference to any agreement, instrument or other document shall be construed as referring to such agreement, instrument or other document as from time to time amended, supplemented, restated or otherwise modified (subject to any restrictions on such amendments, supplements or modifications set forth in the Loan Documents), (ii) any reference to any law shall include all statutory and regulatory provisions consolidating, amending, replacing or interpreting such law and any reference to any law, rule or regulation shall, unless otherwise specified, refer to such law, rule or regulation as amended, modified or supplemented from time to time, (iii) any reference herein to any Person shall be construed to include such Person’s successors and assigns (subject to the restrictions contained in the Loan Documents), (iv) the words “hereto”, “herein”, “hereof” and “hereunder”, and words of similar import when used in any Loan Document, shall be construed to refer to such Loan Document in its entirety and not to any particular provision thereof, (v) with respect to the determination of any time period, the word “from” means “from and including”, the words “to” and “until” each mean “to but excluding” and the word “through” means “to and including” and (vi) any reference in a Loan Document to Articles, Sections, Annexes, Exhibits and Schedules shall be construed to refer

 

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to Articles and Sections of, and Annexes, Exhibits and Schedules to, the Loan Document in which such references appear. No provision of this Agreement or any other Loan Document shall be interpreted or construed against any Person solely because such Person or its legal representative drafted such provision.

Section 1.05    Accounting Terms and Determinations; GAAP. Unless otherwise specified herein, all accounting terms used herein shall be interpreted, all determinations with respect to accounting matters hereunder shall be made, and all financial statements and certificates and reports as to financial matters required to be furnished to the Administrative Agent or the Lenders hereunder shall be prepared, in accordance with GAAP, applied on a basis consistent with the Financial Statements except for changes in which the Borrower’s independent certified public accountants concur and which are disclosed to the Administrative Agent on the next date on which financial statements are required to be delivered to the Lenders pursuant to Section 8.01(a); provided that, unless the Borrower and the Majority Lenders shall otherwise agree in writing, no such change shall modify or affect the manner in which compliance with the covenants set forth herein is computed such that all such computations shall be conducted utilizing financial information presented consistently with prior periods. Notwithstanding anything to the contrary contained herein, all terms of an accounting or financial nature used herein shall be construed, and all computations of amounts and ratios referred to herein shall be made, without giving effect to (i) any election under Financial Accounting Standards Board Accounting Standards Codification 825 (or any other Financial Accounting Standard having a similar result or effect) to value any Debt or other liabilities of the Borrower or any Subsidiary at “fair value”, as defined therein and (ii) any treatment of Debt under Accounting Standards Codification 470-20 or 2015-03 (or any other Accounting Standards Codification or Financial Accounting Standard having a similar result or effect) to value any such Debt in a reduced or bifurcated manner as described therein, and such Debt shall at all times be valued at the full stated principal amount thereof. In the event that any Accounting Change shall occur and such change results in a change in the method of calculation of financial covenants, standards or terms in this Agreement, then the Borrower and the Administrative Agent agree to enter into negotiations in order to amend such provisions of this Agreement so as to reflect equitably such Accounting Changes with the desired result that the criteria for evaluating the Borrower’s financial condition shall be the same after such Accounting Changes as if such Accounting Changes had not been made. Until such time as such an amendment shall have been executed and delivered by the Borrower, the Administrative Agent and the Majority Lenders, all financial covenants, standards and terms in this Agreement shall continue to be calculated or construed as if such Accounting Changes had not occurred.

Section 1.06    Interest Rates. The Administrative Agent does not warrant, nor accept responsibility, nor shall the Administrative Agent have any liability with respect to the administration, submission or any other matter related to any reference rate referred to herein or with respect to any rate (including, for the avoidance of doubt, the selection of such rate and any related spread or other adjustment) that is an alternative or replacement for or successor to any such rate (including, without limitation, any Successor Rate) (or any component of any of the foregoing) or the effect of any of the foregoing, or of any Conforming Changes. The Administrative Agent and its affiliates or other related entities may engage in transactions or other activities that affect any reference rate referred to herein, or any alternative, successor or replacement rate (including, without limitation, any Successor Rate) (or any component of any of the foregoing) or any related spread or other adjustments thereto, in each case, in a manner adverse

 

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to the Borrower. The Administrative Agent may select information sources or services in its reasonable discretion to ascertain any reference rate referred to herein or any alternative, successor or replacement rate (including, without limitation, any Successor Rate) (or any component of any of the foregoing), in each case pursuant to the terms of this Agreement, and shall have no liability to the Borrower, any Lender or any other person or entity for damages of any kind, including direct or indirect, special, punitive, incidental or consequential damages, costs, losses or expenses (whether in tort, contract or otherwise and whether at law or in equity), for any error or other action or omission related to or affecting the selection, determination, or calculation of any rate (or component thereof) provided by any such information source or service.

Section 1.07    Designation and Conversion of Restricted and Unrestricted Subsidiaries.

(a)    Unless designated in writing to the Administrative Agent by the Borrower in accordance with Section 1.07(b), any Person that becomes a Subsidiary of the Borrower or any of its Restricted Subsidiaries after the Effective Date (whether by formation, acquisition, merger or otherwise) shall be classified as a Restricted Subsidiary. On the date hereof, there are no Subsidiaries.

(b)    The Borrower may designate by prior written notice thereof to the Administrative Agent, any Restricted Subsidiary (including a newly formed or newly acquired Subsidiary) as an Unrestricted Subsidiary; provided that (i) both immediately before, and immediately after giving effect, to such designation, (A) no Event of Default or Borrowing Base Deficiency exists or would result from such designation and (B) the Borrower shall be in compliance, on a pro forma basis, with the covenants set forth in Section 9.01; (ii) such Subsidiary is not a “restricted subsidiary” for purposes of any indenture or other agreement governing Debt for borrowed money of the Borrower or a Restricted Subsidiary; (iii) such designation shall be deemed to be an Investment in an amount equal to the fair market value of Borrower’s direct and indirect ownership interest in such Subsidiary and such designation shall be permitted only to the extent such Investment is permitted under Section 9.05 on the date of such designation (without regard to any future fluctuations in value); (iv) such designation shall be deemed to be a Disposition pursuant to which the provisions of Section 2.07(e) and Section 9.12 shall apply; (v) after giving effect to such designation, such Subsidiary is in compliance with the requirements of Section 8.18; and (vi) the Administrative Agent shall have received a certificate of a Responsible Officer, in form and substance reasonably satisfactory to the Administrative Agent, certifying as to the satisfaction of the conditions and matters set forth in clauses (i)-(v) above (and in the case of clause (i)(B) above, setting forth reasonably detailed calculations demonstrating compliance on a pro forma basis with the covenants set forth in Section 9.01). Except as provided in this Section 1.07, no Subsidiary may be designated (and no Restricted Subsidiary may be redesignated) as an Unrestricted Subsidiary.

(c)    The Borrower may designate by prior written notice thereof to the Administrative Agent any Unrestricted Subsidiary to be a Restricted Subsidiary; provided that (i) both immediately before, and immediately after giving effect, to such designation, (A) no Event of Default or Borrowing Base Deficiency exists or would result from such designation, (B) the Borrower shall be in compliance, on a pro forma basis, with the covenants set forth in Section 9.01, (C) the representations and warranties of the Loan Parties contained in this Agreement and each of the other Loan Documents shall be true and correct in all material respects (except that any

 

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representation and warranty that is qualified by materiality shall be true and correct in all respects) on and as of such date as if made on and as of the date of such designation (or, if stated to have been made expressly as of an earlier date, were true and correct in all material respects (except that any representation and warranty that is qualified by materiality shall be true and correct in all respects) as of such date), (iii) the designation of any Unrestricted Subsidiary as a Restricted Subsidiary shall be deemed to be the incurrence at the time of designation of any Investment, Debt, or Liens of such Subsidiary existing at such time, and the Borrower shall be in compliance with Article IX after giving effect to such designation, (iv) immediately after giving effect to such designation, the Borrower and such Subsidiary shall be in compliance with the requirements of Section 8.14 and Section 8.17 and (v) the Administrative Agent shall have received a certificate of a Responsible Officer, in form and substance reasonably satisfactory to the Administrative Agent, certifying as to the satisfaction of the conditions and matters set forth in clauses (i)-(iv) above (and in the case of clause (i)(B) above, setting forth reasonably detailed calculations demonstrating compliance on a pro forma basis with the covenants set forth in Section 9.01).

Section 1.08    Letter of Credit Amounts. Unless otherwise specified herein, the amount of a Letter of Credit at any time shall be deemed to be the amount of such Letter of Credit available to be drawn at such time provided that with respect to any Letter of Credit that, by its terms or the terms of any Letter of Credit Agreement related thereto, provides for one or more automatic increases in the available amount thereof, the amount of such Letter of Credit shall be deemed to be the maximum amount of such Letter of Credit after giving effect to all such increases, whether or not such maximum amount is available to be drawn at such time.

Section 1.09    Divisions. For all purposes under the Loan Documents, in connection with any division or plan of division under Delaware law (or any comparable event under a different jurisdiction’s laws): (a) if any asset, right, obligation or liability of any Person becomes the asset, right, obligation or liability of a different Person, then it shall be deemed to have been transferred from the original Person to the subsequent Person, and (b) if any new Person comes into existence, such new Person shall be deemed to have been organized on the first date of its existence by the holders of its Equity Interests at such time.

ARTICLE II

THE CREDITS

Section 2.01    Commitments. Subject to the terms and conditions set forth herein, each Lender agrees to make Loans to the Borrower during the Availability Period in an aggregate principal amount that will not result in (a) such Lender’s Revolving Credit Exposure exceeding such Lender’s Commitment or (b) the total Revolving Credit Exposures exceeding the total Commitments. Within the foregoing limits and subject to the terms and conditions set forth herein, the Borrower may borrow, prepay and reborrow Loans.

Section 2.02    Loans and Borrowings.

(a)    Borrowings. Each Loan shall be made as part of a Borrowing consisting of Loans made by the Lenders ratably in accordance with their respective Commitments.

 

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(b)    Types of Loans. Subject to Section 3.03, each Borrowing shall be comprised entirely of ABR Loans or Term SOFR Loans as the Borrower may request in accordance herewith. Each Lender at its option may make any Loan by causing any domestic or foreign branch or Affiliate of such Lender to make such Loan; provided that any exercise of such option shall not affect the obligation of the Borrower to repay such Loan in accordance with the terms of this Agreement.

(c)    Minimum Amounts; Limitation on Number of Borrowings. At the commencement of each Interest Period for any Term SOFR Borrowing, such Borrowing shall be in an aggregate amount that is an integral multiple of $100,000 and not less than $1,000,000. At the time that each ABR Borrowing is made, such Borrowing shall be in an aggregate amount that is an integral multiple of $100,000 and not less than $1,000,000; provided that, notwithstanding the foregoing, an ABR Borrowing may be in an aggregate amount that is equal to the entire unused balance of the total Commitments or that is required to finance the reimbursement of an LC Disbursement as contemplated by Section 2.08(e). Borrowings of more than one Type may be outstanding at the same time; provided that there shall not at any time be more than a total of seven (7) Term SOFR Borrowings outstanding. Notwithstanding any other provision of this Agreement, the Borrower shall not be entitled to request, or to elect to convert or continue, any Borrowing if the Interest Period requested with respect thereto would end after the Maturity Date.

(d)    Notes. Any Lender may request that Loans made by it be evidenced by a single Note, dated, in the case of (i) any Lender party hereto as of the date of this Agreement, as of the Effective Date, (ii) any Lender that becomes a party hereto pursuant to an Assignment and Assumption, as of the effective date of such Assignment and Assumption, or (iii) in the case of a Lender that becomes a party hereto in connection with an increase in the Aggregate Elected Commitment pursuant to Section 2.06(c), as of the effective date of such increase, payable to such Lender in a principal amount equal to its Maximum Credit Amount as in effect on such date, and otherwise duly completed. In the event that any Lender’s Maximum Credit Amount increases or decreases for any reason (whether pursuant to Section 2.06, Section 12.04(b) or otherwise), upon the request of such Lender, the Borrower shall deliver or cause to be delivered on the effective date of such increase or decrease, a new Note payable to such Lender in a principal amount equal to its Maximum Credit Amount after giving effect to such increase or decrease, and otherwise duly completed and such Lender shall promptly return to the Borrower the previously issued Note held by such Lender. The date, amount, Type, interest rate and, if applicable, Interest Period of each Loan made by each Lender, and all payments made on account of the principal thereof, may be recorded by such Lender on its books for its Note, and, prior to any transfer, may be endorsed by such Lender on a schedule attached to such Note or any continuation thereof or on any separate record maintained by such Lender. Failure to make any such notation or to attach a schedule shall not affect any Lender’s or the Borrower’s rights or obligations in respect of such Loans or affect the validity of such transfer by any Lender of its Note.

(e)    Obligations of Lenders Several. The obligations of the Lenders to make Loans, to fund participations in Letters of Credit and to make payments pursuant to Section 12.03(c) are several and not joint. The failure of any Lender to make any Loan, to fund any such participation or to make any payment under Section 12.03(c) on any date required hereunder shall not relieve any other Lender of its corresponding obligation to do so on such date, and no Lender shall be responsible for the failure of any other Lender to so make its Loan, to purchase its participation or to make its payment under Section 12.03(c).

 

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Section 2.03    Requests for Borrowings. To request a Borrowing, the Borrower shall notify the Administrative Agent of such request by telephone or electronic communication (a) in the case of a Term SOFR Borrowing, not later than 12:00 noon, Houston, Texas time, two Business Days before the date of the proposed Borrowing (or, with respect to the initial Borrowing on the Effective Date, such lesser period of time as approved by the Administrative Agent) or (b) in the case of an ABR Borrowing, not later than 12:00 noon, Houston, Texas time, on the date of the proposed Borrowing; provided that no such notice shall be required for any deemed request of an ABR Borrowing to finance the reimbursement of an LC Disbursement as provided in Section 2.08(e). Each such Borrowing Request shall be irrevocable and shall be confirmed promptly by hand delivery, facsimile or electronic communication to the Administrative Agent of a written Borrowing Request and signed by a Responsible Officer of the Borrower; provided that, subject to Section 5.02, the Borrower may condition a Borrowing Request on the consummation of an acquisition, Investment or other identifiable event or condition and any such Borrowing Request may be revoked by the Borrower if such acquisition or Investment is not consummated, or such event or condition does not occur, on the date specified in the applicable Borrowing Request. Each such telephonic and written Borrowing Request shall specify the following information in compliance with Section 2.02:

(a)    the aggregate amount of the requested Borrowing;

(b)    the date of such Borrowing, which shall be a Business Day;

(c)    whether such Borrowing is to be an ABR Borrowing or a Term SOFR Borrowing;

(d)    in the case of a Term SOFR Borrowing, the initial Interest Period to be applicable thereto, which shall be a period contemplated by the definition of the term “Interest Period”;

(e)    the amount of the then effective Borrowing Base, the amount of the then effective Aggregate Elected Commitment, the current total Revolving Credit Exposures (without regard to the requested Borrowing) and the pro forma total Revolving Credit Exposures (giving effect to the requested Borrowing); and

(f)    the location and number of the Borrower’s account (or another account as directed by the Borrower) to which funds are to be disbursed, which shall comply with the requirements of Section 2.05.

If no election as to the Type of Borrowing is specified, then the requested Borrowing shall be an ABR Borrowing. If no Interest Period is specified with respect to any requested Term SOFR Borrowing, then the Borrower shall be deemed to have selected an Interest Period of one month’s duration. Each Borrowing Request shall constitute a representation that (a) the amount of the requested Borrowing shall not cause the total Revolving Credit Exposures to exceed the total Commitments (i.e., the lesser of (A) the Aggregate Maximum Credit Amounts, (B) the Aggregate Elected Commitment and (C) the then effective Borrowing Base) and (b) after giving pro forma effect to the requested Borrowing, no Excess Cash exists.

 

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Promptly following receipt of a Borrowing Request in accordance with this Section 2.03, the Administrative Agent shall advise each Lender of the details thereof and of the amount of such Lender’s Loan to be made as part of the requested Borrowing.

Section 2.04    Interest Elections.

(a)    Conversion and Continuance. Each Borrowing initially shall be of the Type specified in the applicable Borrowing Request and, in the case of a Term SOFR Borrowing, shall have an initial Interest Period as specified in such Borrowing Request. Thereafter, the Borrower may elect to convert such Borrowing to a different Type or to continue such Borrowing and, in the case of a Term SOFR Borrowing, may elect Interest Periods therefor, all as provided in this Section 2.04. The Borrower may elect different options with respect to different portions of the affected Borrowing, in which case each such portion shall be allocated ratably among the Lenders holding the Loans comprising such Borrowing, and the Loans comprising each such portion shall be considered a separate Borrowing.

(b)    Interest Election Requests. To make an election pursuant to this Section 2.04, the Borrower shall notify the Administrative Agent of such election by delivering a written Interest Election Request signed by a Responsible Officer of the Borrower or by telephone by the time that a Borrowing Request would be required under Section 2.03 if the Borrower were requesting a Borrowing of the Type resulting from such election to be made on the effective date of such election. Each such telephonic Interest Election Request shall be irrevocable and shall be confirmed promptly by hand delivery, facsimile or electronic communication to the Administrative Agent of a written Interest Election Request signed by a Responsible Officer of the Borrower.

(c)    Information in Interest Election Requests. Each telephonic and written Interest Election Request shall specify the following information in compliance with Section 2.02:

(i)    the Borrowing to which such Interest Election Request applies and, if different options are being elected with respect to different portions thereof, the portions thereof to be allocated to each resulting Borrowing (in which case the information to be specified pursuant to Section 2.04(c)(iii) and (iv) shall be specified for each resulting Borrowing);

(ii)    the effective date of the election made pursuant to such Interest Election Request, which shall be a Business Day;

(iii)    whether the resulting Borrowing is to be an ABR Borrowing or a Term SOFR Borrowing; and

(iv)    if the resulting Borrowing is a Term SOFR Borrowing, the Interest Period to be applicable thereto after giving effect to such election, which shall be a period contemplated by the definition of the term “Interest Period”.

 

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If any such Interest Election Request requests a Term SOFR Borrowing but does not specify an Interest Period, then the Borrower shall be deemed to have selected an Interest Period of one month’s duration.

(d)    Notice to Lenders by the Administrative Agent. Promptly following receipt of an Interest Election Request, the Administrative Agent shall advise each Lender of the details thereof and of such Lender’s portion of each resulting Borrowing.

(e)    Effect of Failure to Deliver Timely Interest Election Request and Events of Default and Borrowing Base Deficiencies on Interest Election. If the Borrower fails to deliver a timely Interest Election Request with respect to a Term SOFR Borrowing prior to the end of the Interest Period applicable thereto, then, unless such Borrowing is repaid as provided herein, at the end of such Interest Period such Borrowing shall be converted on such date to an ABR Borrowing. Notwithstanding any contrary provision hereof, if a Borrowing Base Deficiency or an Event of Default has occurred and is continuing and the Majority Lenders have elected in writing to the Borrower and the Administrative Agent to not allow such conversions or continuations: (i) no outstanding Borrowing may be converted to or continued as a Term SOFR Borrowing (and any Interest Election Request that requests the conversion of any Borrowing to, or continuation of any Borrowing as, a Term SOFR Borrowing shall be ineffective) and (ii) unless repaid, each Term SOFR Borrowing shall be converted to an ABR Borrowing at the end of the Interest Period applicable thereto.

Section 2.05    Funding of Borrowings.

(a)    Funding by Lenders. Each Lender shall make each Loan to be made by it hereunder on the proposed date thereof by wire transfer of immediately available funds by 1:00 p.m., Houston, Texas time, to the account of the Administrative Agent most recently designated by it for such purpose by notice to the Lenders. The Administrative Agent will make such Loans available to the Borrower by promptly delivering or crediting (as applicable) the amounts so received, in like funds, to an account of the Borrower, subject to, after the Control Agreement Delivery Date, a Control Agreement, and designated by the Borrower in the applicable Borrowing Request; provided that ABR Loans made to finance the reimbursement of an LC Disbursement as provided in Section 2.08(e) shall be remitted by the Administrative Agent to the Issuing Bank. Nothing herein shall be deemed to obligate any Lender to obtain the funds for its Loan in any particular place or manner or to constitute a representation by any Lender that it has obtained or will obtain the funds for its Loan in any particular place or manner.

(b)    Presumption of Funding by the Lenders. Unless the Administrative Agent shall have received notice from a Lender prior to the proposed date of any Borrowing that such Lender will not make available to the Administrative Agent such Lender’s share of such Borrowing, the Administrative Agent may assume that such Lender has made such share available on such date in accordance with Section 2.05(a) and may, in reliance upon such assumption, make available to the Borrower a corresponding amount. In such event, if a Lender has not in fact made its share of the applicable Borrowing available to the Administrative Agent, then the applicable Lender and the Borrower severally agree to pay to the Administrative Agent forthwith on demand such corresponding amount in immediately available funds with interest thereon, for each day from and including the date such amount is made available to the Borrower to but excluding the date of

 

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payment to the Administrative Agent, at (i) in the case of such Lender, the greater of the Federal Funds Rate and a rate determined by the Administrative Agent in accordance with banking industry rules on interbank compensation, plus any administrative, processing or similar fees customarily charged by the Administrative Agent in connection with the foregoing or (ii) in the case of the Borrower, the interest rate applicable to ABR Loans. If such Lender pays such amount to the Administrative Agent, then such amount shall constitute such Lender’s Loan included in such Borrowing. If the Borrower and such Lender shall pay such interest to the Administrative Agent for the same or an overlapping period, the Administrative Agent shall promptly remit to the Borrower the amount of such interest paid by the Borrower for such period. Any payment by the Borrower shall be without prejudice to any claim the Borrower may have against a Lender that shall have failed to make such payment to the Administrative Agent. A notice of the Administrative Agent to any Lender or the Borrower with respect to any amount owing under this clause (b) shall be conclusive, absent manifest error.

(c)    Failure to Satisfy Conditions Precedent. If any Lender makes available to the Administrative Agent funds for any Loan to be made by such Lender as provided in the foregoing provisions of this Article II, and such funds are not made available to the Borrower by the Administrative Agent because the conditions to the applicable credit extension set forth in Article IV are not satisfied or waived in accordance with the terms hereof, the Administrative Agent shall return such funds (in like funds as received from such Lender) to such Lender, without interest.

Section 2.06    Termination, Revision and Reduction of Commitments and Aggregate Maximum Credit Amounts; Increase, Reduction and Termination of Aggregate Elected Commitment.

(a)    Scheduled Termination of Commitments. Unless previously terminated, the Commitments shall terminate on the Maturity Date. If at any time the Aggregate Maximum Credit Amount, the Aggregate Elected Commitment or the Borrowing Base is terminated or reduced to zero, then the Commitments shall terminate on the effective date of such termination or reduction.

(b)    Optional Termination and Reduction of Aggregate Maximum Credit Amounts.

(i)    The Borrower may at any time terminate, or from time to time reduce, the Aggregate Maximum Credit Amounts; provided that (A) each reduction of the Aggregate Maximum Credit Amounts shall be in an amount that is an integral multiple of $500,000 and not less than $1,000,000 and (B) the Borrower shall not terminate or reduce the Aggregate Maximum Credit Amounts if, after giving effect to any concurrent prepayment of the Loans in accordance with Section 3.04(c)(i), the total Revolving Credit Exposures would exceed the total Commitments.

(ii)    The Borrower shall notify the Administrative Agent of any election to terminate or reduce the Aggregate Maximum Credit Amounts under Section 2.06(b)(i) at least three Business Days prior to the effective date of such termination or reduction, specifying such election and the effective date thereof. Promptly following receipt of any notice, the Administrative Agent shall advise the Lenders of the contents thereof. Each notice delivered by

 

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the Borrower pursuant to this Section 2.06(b)(ii) shall be irrevocable; provided that such notice may state that it is conditioned upon the occurrence of one or more specified events (including the effectiveness of other credit facilities), in which case such notice may be revoked by the Borrower (by notice to the Administrative Agent on or prior to the specified effective date) if such specified event(s) do not occur. Any termination or reduction of the Aggregate Maximum Credit Amounts shall be permanent and may not be reinstated. Each reduction of the Aggregate Maximum Credit Amounts pursuant to this Section 2.06(b)(ii) shall be made ratably among the Lenders in accordance with each Lender’s Applicable Percentage.

(c)    Increase, Reduction and Termination of Aggregate Elected Commitment.

(i)    Subject to the conditions set forth in Section 2.06(c)(ii) and the prior written approval of the Administrative Agent (not to be unreasonably withheld, conditioned or delayed), the Borrower may increase the Aggregate Elected Commitment then in effect by increasing the Elected Commitment of a Lender and/or by causing a Person that at such time is not a Lender to become a Lender (any such Person that is not at such time a Lender and becomes a Lender, an “Additional Lender”). Notwithstanding anything to the contrary contained in this Agreement, in no case shall an Additional Lender be a natural person (or a holding company, investment vehicle or trust for, or owned and operated by or for the primary benefit of one or more natural persons), the Borrower or any Affiliate of the Borrower.

(ii)    Any increase in the Aggregate Elected Commitment shall be subject to the following additional conditions:

(A)    Any increase in the Aggregate Elected Commitment shall first be offered to each of the Lenders, who shall have until the earlier of (1) five (5) Business Days from the date of such offer and (2) the first date on which all Lenders have declined to increase their Elected Commitments, to elect to increase their applicable Elected Commitment and, if a Lender elects to increase its Elected Commitment during such period, the Borrower and such Lender shall execute and deliver an Elected Commitment Increase Certificate (as defined below), before the Borrower may elect to cause an Additional Lender to become a Lender;

(B)    such increase shall not be less than $5,000,000 or, if less, the amount by which the Borrowing Base exceeds the Aggregate Elected Commitment prior to giving effect to such increase, unless the Administrative Agent otherwise consents, and no such increase shall be permitted if after giving effect thereto the Aggregate Elected Commitment exceed the Borrowing Base then in effect;

(C)    following any Scheduled Redetermination, the Borrower may not increase the Aggregate Elected Commitment more than twice before the next Scheduled Redetermination, unless the Administrative Agent otherwise consents (for the sake of clarity, all increases in the Aggregate Elected Commitment effective on a single date shall be deemed a single increase in the Aggregate Elected Commitment for purposes of this Section 2.06(c)(ii)(C));

(D)    no Default or Event of Default shall have occurred and be continuing on the effective date of such increase;

 

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(E)    no Lender’s Elected Commitment may be increased without the consent of such Lender;

(F)    on the effective date of such increase, no Term SOFR Borrowings shall be outstanding or if any Term SOFR Borrowings are outstanding, then the effective date of such increase shall be the last day of the Interest Period in respect of such Term SOFR Borrowings unless the Borrower pays compensation required by Section 5.02 or such compensation is waived by each Lender affected thereby;

(G)    if the Aggregate Elected Commitment is increased by increasing the Elected Commitment of a Lender, the Borrower and such Lender shall execute and deliver to the Administrative Agent a certificate substantially in the form of Exhibit I (an “Elected Commitment Increase Certificate”); and

(H)    after the expiration of the time period set forth in clause (A) above, if the Borrower elects to increase the Aggregate Elected Commitment by causing an Additional Lender to become a party to this Agreement, then the Borrower and such Additional Lender shall execute and deliver to the Administrative Agent a certificate substantially in the form of Exhibit J (an “Additional Lender Certificate”), together with an Administrative Questionnaire and a processing and recordation fee of $3,500 (provided that the Administrative Agent may, in its discretion, elect to waive such processing and recordation fee in connection with any such increase), and the Borrower shall (1) if requested by the Additional Lender, deliver a Note payable to such Additional Lender in a principal amount equal to its Maximum Credit Amount, and otherwise duly completed and (2) pay any applicable fees as may have been agreed to between the Borrower and the Additional Lender, and, to the extent applicable and agreed to by the Borrower, the Administrative Agent;

(iii)    Subject to acceptance and recording thereof pursuant to Section 2.06(c)(iv), from and after the effective date specified in the Elected Commitment Increase Certificate or the Additional Lender Certificate: (A) the amount of the Aggregate Elected Commitment shall be increased as set forth therein, and (B) in the case of an Additional Lender Certificate, any Additional Lender party thereto shall be a party to this Agreement and have the rights and obligations of a Lender under this Agreement and the other Loan Documents. In addition, the Lender or the Additional Lender, as applicable, shall purchase a pro rata portion of the outstanding Loans of each of the other Lenders (and such Lenders hereby agree to sell and to take all such further action to effectuate such sale) such that each Lender (including any Additional Lender, if applicable) shall hold its Applicable Percentage of the outstanding Loans (and participation interests) after giving effect to the increase in the Aggregate Elected Commitment (and the resulting modifications of each Lender’s Maximum Credit Amount pursuant to Section 2.06(c)(iv) or Section 2.06(c)(v)).

(iv)    Upon its receipt of a duly completed Elected Commitment Increase Certificate or an Additional Lender Certificate, executed by the Borrower and the Lender or by the Borrower and the Additional Lender party thereto, as applicable, the processing and recording fee referred to in Section 2.06(c)(ii), and, if required, the Administrative Questionnaire referred to in Section 2.06(c)(ii), the Administrative Agent shall accept such Elected Commitment Increase Certificate or Additional Lender Certificate and record the information contained therein in the

 

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Register required to be maintained by the Administrative Agent pursuant to Section 12.04(b)(iv). No increase in the Aggregate Elected Commitment shall be effective for purposes of this Agreement unless it has been recorded in the Register as provided in this Section 2.06(c)(iv).

(v)    Upon any increase in the Aggregate Elected Commitment pursuant to Section 2.06(c)(iv), (A) each Lender’s Maximum Credit Amounts shall be automatically deemed amended to the extent necessary so that each such Lender’s Applicable Percentage equals the percentage of the Aggregate Elected Commitment represented by such Lender’s Elected Commitment, in each case after giving effect to such increase, and (B) Annex I to this Agreement shall be deemed amended to reflect the Elected Commitment of each Lender (including any Additional Lender) as thereby increased, any changes in the Lenders’ Maximum Credit Amounts pursuant to the foregoing clause (A), and any resulting changes in the Lenders’ Applicable Percentages.

(vi)    The Borrower may from time to time terminate or reduce the Aggregate Elected Commitment; provided that (A) each reduction of the Aggregate Elected Commitment shall be in an amount that is an integral multiple of $1,000,000 and not less than $5,000,000 and (B) the Borrower shall not reduce the Aggregate Elected Commitment if, after giving effect to any concurrent prepayment of the Loans in accordance with Section 3.04(c), the total Revolving Credit Exposures of all Lenders would exceed the Aggregate Elected Commitment as reduced.

(vii)    The Borrower shall notify the Administrative Agent of any election to terminate or reduce the Aggregate Elected Commitment under Section 2.06(c)(vi) at least three (3) Business Days prior to the effective date of such termination or reduction (or such lesser period as may be reasonably acceptable to the Administrative Agent), specifying such election and the effective date thereof. Promptly following receipt of any notice, the Administrative Agent shall advise the Lenders of the contents thereof. Each notice delivered by the Borrower pursuant to this Section 2.06(c)(vii) shall be irrevocable; provided that such notice may state that it is conditioned upon the occurrence of one or more specified events (including the effectiveness of other credit facilities), in which case such notice may be revoked by the Borrower (by notice to the Administrative Agent on or prior to the specified effective date) if such specified event(s) do not occur. Any termination or reduction of the Aggregate Elected Commitment shall be permanent and may not be reinstated, except pursuant to Section 2.06(c)(i). Each reduction of the Aggregate Elected Commitment shall be made ratably among the Lenders in accordance with each Lender’s Applicable Percentage.

(viii)    Upon any redetermination or other adjustment in the Borrowing Base pursuant to this Agreement that would otherwise result in the Borrowing Base becoming less than the Aggregate Elected Commitment, the Aggregate Elected Commitment shall be automatically reduced (ratably among the Lenders in accordance with each Lender’s Applicable Percentage) so that they equal such redetermined Borrowing Base (and Annex I) shall be deemed amended to reflect such amendments to each Lender’s Elected Commitment and the Aggregate Elected Commitment).

 

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(ix)    Contemporaneously with any increase in the Borrowing Base pursuant to this Agreement, if (A) the Borrower elects to increase the Aggregate Elected Commitment and (B) each Lender has consented to such increase in its Elected Commitment, then the Aggregate Elected Commitment shall be increased (ratably among the Lenders in accordance with each Lender’s Applicable Percentage) by the amount requested by the Borrower without the requirement that any Lender deliver an Elected Commitment Increase Certificate or that the Borrower pay any amounts under Section 5.02, and Annex I shall be deemed amended to reflect such amendments to each Lender’s Elected Commitment and the Aggregate Elected Commitment. The Administrative Agent shall record the information regarding such increases in the Register required to be maintained by the Administrative Agent pursuant to Section 12.04(b)(iv).

(x)    If, after giving effect to any reduction in the Aggregate Elected Commitment pursuant to this Section 2.06(c), the total Revolving Credit Exposures exceed the as reduced Aggregate Elected Commitment, then the Borrower shall (A) prepay the Borrowings on the date of such termination or reduction in an aggregate principal amount equal to such excess, and (B) if any excess remains after prepaying all of the Borrowings as a result of an LC Exposure, transfer to the Administrative Agent on behalf of the Lenders an amount equal to such excess to be held as cash collateral as provided in Section 2.08(j).

Section 2.07    Borrowing Base.

(a)    Borrowing Base. For the period from and including the Effective Date until the first Redetermination Date, the amount of the Borrowing Base shall be $300,000,000. Notwithstanding the foregoing, the Borrowing Base may be subject to further adjustments from time to time pursuant to Section 2.07(e), Section 2.07(f) or Section 8.13(c).

(b)    Scheduled and Interim Redeterminations. The Borrowing Base shall be redetermined semi-annually in accordance with this Section 2.07 (each such redetermination, a “Scheduled Redetermination”), and, subject to Section 2.07(d), such redetermined Borrowing Base shall become effective and applicable to the Borrower, the Administrative Agent, the Issuing Bank and the Lenders on April 1st and October 1st of each year (or, in each case, such date promptly thereafter as reasonably practicable), commencing October 1, 2022. In addition, (i) the Borrower may, by notifying the Administrative Agent thereof, one time between successive Scheduled Redeterminations (including prior to the first Scheduled Redetermination), elect to cause the Borrowing Base to be redetermined, (ii) after the first Scheduled Redetermination, the Administrative Agent may, at the direction of the Required Lenders, by notifying the Borrower thereof, one time between successive Scheduled Redeterminations, elect to cause the Borrowing Base to be redetermined, and (iii) the Borrower may, by notifying the Administrative Agent of any acquisition of Oil and Gas Properties by the Loan Parties with a purchase price in the aggregate of at least five percent (5%) of the then effective Borrowing Base, elect to cause the Borrowing Base to be redetermined (in the case of each of the foregoing clauses (i), (ii) and (ii), an “Interim Redetermination”), in each case in accordance with this Section 2.07.

(c)    Scheduled and Interim Redetermination Procedure.

(i)    Each Scheduled Redetermination and each Interim Redetermination shall be effectuated as follows: upon receipt by the Administrative Agent of (A) the Reserve Report and the certificate required to be delivered by the Borrower to the Administrative Agent, in the case of a Scheduled Redetermination, pursuant to Section 8.12(a) and (c), and, in the case

 

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of an Interim Redetermination, pursuant to Section 8.12(b) and (c), and (B) such other reports, data and supplemental information, including, without limitation, the information provided pursuant to Section 8.12(c), as may, from time to time, be reasonably requested by the Administrative Agent or the Majority Lenders (the Reserve Report, such certificate and such other reports, data and supplemental information being the “Engineering Reports”), the Administrative Agent shall evaluate the information contained in the Engineering Reports and shall, in its sole discretion, propose a new Borrowing Base (the “Proposed Borrowing Base”) based upon such information and such other information (including, without limitation, the status of title information with respect to the Oil and Gas Properties as described in the Engineering Reports and the existence of any other Debt) as the Administrative Agent deems appropriate in its sole discretion and consistent with its normal oil and gas lending criteria as it exists at the particular time. In no event shall the Proposed Borrowing Base exceed the Aggregate Maximum Credit Amounts.

(ii)    The Administrative Agent shall notify the Borrower and the Lenders of the Proposed Borrowing Base (the “Proposed Borrowing Base Notice”):

(A)    in the case of a Scheduled Redetermination (1) if the Administrative Agent shall have received the Engineering Reports required to be delivered by the Borrower pursuant to Section 8.12(a) and (c) in a timely and complete manner, then on or before March 15th and September 15th of such year following the date of delivery or (2) if the Administrative Agent shall not have received the Engineering Reports required to be delivered by the Borrower pursuant to Section 8.12(a) and (c) in a timely and complete manner, then promptly after the Administrative Agent has received complete Engineering Reports from the Borrower and has had a reasonable opportunity to determine the Proposed Borrowing Base in accordance with Section 2.07(c)(i); and

(B)    in the case of an Interim Redetermination, promptly, and in any event, within fifteen (15) days after the Administrative Agent has received the required Engineering Reports.

(iii)    Subject to Section 12.02(b)(ii) with respect to any Defaulting Lender, any Proposed Borrowing Base that would increase the Borrowing Base then in effect must be approved by all of the Lenders (in each Lender’s sole discretion) as provided in this Section 2.07(c)(iii); and any Proposed Borrowing Base that would decrease or maintain the Borrowing Base then in effect must be approved or be deemed to have been approved by the Required Lenders (in each Lender’s sole discretion) as provided in this Section 2.07(c)(iii). Upon receipt of the Proposed Borrowing Base Notice, each Lender shall have fifteen (15) days to agree with the Proposed Borrowing Base or disagree with the Proposed Borrowing Base by proposing an alternate Borrowing Base. All decisions regarding the Borrowing Base hereunder shall be made by each Lender in its sole discretion as such Lender deems appropriate and consistent with its normal oil and gas lending criteria as it exists at the particular time. If at the end of such fifteen (15) days, any Lender has not communicated its approval or disapproval in writing to the Administrative Agent, such silence shall be deemed to be (A) in the case of a Proposed Borrowing Base that would increase the Borrowing Base then in effect, a disapproval of the Proposed Borrowing Base and (B) in the case of a Proposed Borrowing Base that would decrease or maintain the Borrowing Base then in effect, an approval of the Proposed Borrowing Base. If, at the end of

 

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such 15-day period, all of the Lenders, in the case of a Proposed Borrowing Base that would increase the Borrowing Base then in effect, or the Required Lenders, in the case of a Proposed Borrowing Base that would decrease or maintain the Borrowing Base then in effect, have approved or deemed to have approved, as aforesaid, then the Proposed Borrowing Base shall become the new Borrowing Base, effective on the date specified in Section 2.07(d). If, however, at the end of such 15-day period, all of the Lenders or the Required Lenders, as applicable, have not approved or been deemed to have approved the Proposed Borrowing Base, then the Administrative Agent shall poll the Lenders to ascertain the highest Borrowing Base then acceptable to (x) in the case of a decrease or reaffirmation, a number of Lenders sufficient to constitute the Required Lenders or (y) in the case of an increase, all of the Lenders, and such amount shall become the new Borrowing Base, effective on the date specified in Section 2.07(d).

(d)    Effectiveness of a Redetermined Borrowing Base. After a redetermined Borrowing Base is approved or is deemed to have been approved by all of the Lenders or the Required Lenders, as applicable, pursuant to Section 2.07(c)(iii), the Administrative Agent shall notify the Borrower and the Lenders of the amount of the redetermined Borrowing Base (the “New Borrowing Base Notice”), and such amount shall become the new Borrowing Base, effective and applicable to the Borrower, the Administrative Agent, the Issuing Bank and the Lenders:

(i)    in the case of a Scheduled Redetermination, (A) if the Administrative Agent shall have received the Engineering Reports required to be delivered by the Borrower pursuant to Sections 8.12(a) and (c) in a timely and complete manner, then on the April 1st or October 1st, as applicable, following such notice, or (B) if the Administrative Agent shall not have received the Engineering Reports required to be delivered by the Borrower pursuant to Sections 8.12(a) and (c) in a timely and complete manner, then on the Business Day next succeeding delivery of such notice; and

(ii)    in the case of an Interim Redetermination, on the Business Day next succeeding delivery of such New Borrowing Base Notice (or such date as the Administrative Agent, the Lenders and the Borrower may otherwise agree to).

Such amount shall then become the Borrowing Base until the next Scheduled Redetermination Date, the next Interim Redetermination Date or the next adjustment to the Borrowing Base under Section 2.07(e), Section 2.07(f) or Section 8.13(c), whichever occurs first. Notwithstanding the foregoing, no Scheduled Redetermination or Interim Redetermination shall become effective until the New Borrowing Base Notice related thereto is received by the Borrower.

(e)    Reduction of Borrowing Base Related to Dispositions of Borrowing Base Properties and/or Liquidation of Swap Agreements. If (i) any Swap Agreement to which any Loan Party is a party is Liquidated or (ii) any Loan Party Disposes of any Borrowing Base Property or Equity Interests in any Loan Party owning Borrowing Base Properties, and the Borrowing Base value assigned to the Liquidated portion of such Swap Agreement (after giving effect to any other Swap Agreements executed by the Borrower or any Guarantor contemporaneously with the Liquidation of such Swap Agreements or subsequent to the most recent Scheduled Redetermination Date) or the Borrowing Base value of such Borrowing Base Property (or in the case of any Disposition of Equity Interests in any Loan Party owning Borrowing Base Properties, the Borrowing Base value of the Borrowing Base Properties owned by such Loan Party), as

 

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applicable, in each case as determined by the Administrative Agent, when combined with the sum of (A) the Borrowing Base value of all other Borrowing Base Properties Disposed of (including, in the case of any Disposition of Equity Interests in any Loan Party owning Borrowing Base Properties, the Borrowing Base value of such Borrowing Base Properties owned by such Loan Party), in each case since the most recent Scheduled Redetermination Date and (B) the Borrowing Base value of the Liquidated portion of other Swap Agreements Liquidated since the most recent Scheduled Redetermination Date, exceeds seven and one half percent (7.5%) of the Borrowing Base as then in effect (as determined by the Administrative Agent), individually or in the aggregate, then the Borrowing Base then in effect shall be reduced by an amount equal to the value, if any, assigned to the Liquidated portion of such Swap Agreement in the then effective Borrowing Base and/or the value assigned to such Disposed Borrowing Base Property in the most recently delivered Reserve Report, as the case may be, in each case as determined by the Administrative Agent. The Borrowing Base as so reduced shall become the new Borrowing Base immediately upon the date of such Disposition or Liquidation, as the case may be, effective and applicable to the Borrower, the Administrative Agent, the Issuing Bank and the Lenders on such date until the next redetermination or adjustment thereof hereunder. For purposes of this Section 2.07(e), until the first Scheduled Redetermination Date occurs hereunder, the phrase “the most recent Scheduled Redetermination Date” shall mean “the Effective Date”.

(f)    Reduction of Borrowing Base Upon Incurrence of Permitted Additional Debt. If the Borrower incurs any Permitted Additional Debt in accordance with Section 9.02(g) (other than any Permitted Additional Debt incurred to refinance then-outstanding Permitted Additional Debt, but only to the extent that the aggregate principal amount of the new Permitted Additional Debt incurred to refinance such outstanding Permitted Additional Debt does not result in an increase in the principal amount thereof except in respect of an increase in the principal amount as a result of customary fees and expenses related to the refinancing of such outstanding Permitted Additional Debt), unless the Borrower and the Required Lenders shall otherwise agree, the Borrowing Base then in effect shall be reduced by an amount equal to the product of 0.25 multiplied by the stated principal amount of such Permitted Additional Debt (for the avoidance of doubt, without regard to any original issue discount). The Borrowing Base as so reduced shall become the new Borrowing Base immediately upon the date of such incurrence, effective and applicable to the Borrower, the Administrative Agent, the Issuing Banks and the Lenders on such date until the next redetermination or adjustment thereof hereunder.

Section 2.08    Letters of Credit.

(a)    General. Subject to the terms and conditions set forth herein, the Borrower may request the issuance of dollar denominated Letters of Credit as the applicant thereof for the support of its or any Guarantor’s obligations, in a form reasonably acceptable to the Administrative Agent and the Issuing Bank, at any time and from time to time during the period from and including the Effective Date until the day which is five (5) Business Days prior to the Termination Date; provided that the Borrower may not request the issuance, amendment, renewal or extension of Letters of Credit hereunder if a Borrowing Base Deficiency exists at such time or would exist as a result thereof. In the event of any inconsistency between the terms and conditions of this Agreement and the terms and conditions of any form of letter of credit application or other agreement submitted by the Borrower to, or entered into by the Borrower with, the Issuing Bank relating to any Letter of Credit, the terms and conditions of this Agreement shall control.

 

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(b)    Notice of Issuance, Amendment, Renewal, Extension; Certain Conditions. All letters of credit issued pursuant to the Existing Credit Agreement are deemed to have been issued pursuant hereto, and from and after the Effective Date, shall be subject to and governed by the terms and conditions hereof. To request the issuance of a Letter of Credit (or the amendment, renewal or extension of an outstanding Letter of Credit), the Borrower shall hand deliver or facsimile (or transmit by electronic communication, if arrangements for doing so have been approved by the Issuing Bank) to the Issuing Bank and the Administrative Agent (not less than three (3) Business Days in advance of the requested date of issuance, amendment, renewal or extension) a notice:

(i)    requesting the issuance of a Letter of Credit or identifying the Letter of Credit to be amended, renewed, reinstated or extended;

(ii)    specifying the date of issuance, amendment, renewal, reinstatement or extension (which shall be a Business Day);

(iii)    specifying the date on which such Letter of Credit is to expire (which shall comply with Section 2.08(c));

(iv)    specifying the amount of such Letter of Credit;

(v)    specifying the name and address of the beneficiary thereof, the purpose and nature of the requested Letter of Credit and such other information as shall be necessary to prepare, amend, renew, reinstate or extend such Letter of Credit; and

(vi)    specifying the amount of the then effective Borrowing Base and the then effective Aggregate Elected Commitment and whether a Borrowing Base Deficiency exists at such time, the current total Revolving Credit Exposures (without regard to the requested Letter of Credit or the requested amendment, renewal or extension of an outstanding Letter of Credit) and the pro forma total Revolving Credit Exposures (giving effect to the requested Letter of Credit or the requested amendment, renewal or extension of an outstanding Letter of Credit).

A Letter of Credit shall be issued, amended, renewed, reinstated or extended only if (and each notice shall constitute a representation and warranty by the Borrower that), after giving effect to the requested issuance, amendment, renewal, reinstatement or extension, as applicable, (i) the LC Exposure shall not exceed the LC Commitment, (ii) no Lender’s Revolving Credit Exposure shall exceed its Commitment and (iii) the total Revolving Credit Exposures shall not exceed the total Commitments (i.e., the lesser of (A) the Aggregate Maximum Credit Amounts, (B) the Aggregate Elected Commitment and (C) the then effective Borrowing Base).

If requested by the Issuing Bank, the Borrower also shall submit a letter of credit application and reimbursement agreement on the Issuing Bank’s standard form in connection with any request for a Letter of Credit; provided that, in the event of any conflict between such application and the terms of this Agreement, the terms of this Agreement shall control.

The Issuing Bank shall not be under any obligation to issue any Letter of Credit if: (i) any order, judgment or decree of any Governmental Authority or arbitrator shall by its terms purport to enjoin or restrain the Issuing Bank from issuing such Letter of Credit, or any law applicable to

 

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the Issuing Bank or any request or directive (whether or not having the force of law) from any Governmental Authority with jurisdiction over the Issuing Bank shall prohibit, or require or request that the Issuing Bank refrain from, the issuance of letters of credit generally or such Letter of Credit in particular or shall impose upon the Issuing Bank with respect to such Letter of Credit any restriction, reserve or capital requirement (for which the Issuing Bank is not otherwise compensated hereunder) not in effect on the Effective Date, or shall impose upon the Issuing Bank any unreimbursed loss, cost or expense that was not applicable on the Effective Date and that the Issuing Bank in good faith deems material to it, (ii) the issuance of such Letter of Credit would violate one or more policies of the Issuing Bank applicable to letters of credit generally, (iii) except as otherwise agreed by the Administrative Agent and the Issuing Bank, the Letter of Credit is in an initial stated amount less than $100,000 or (iv) if any Lender is at the time a Defaulting Lender, unless the Issuing Bank has entered into arrangements, including the delivery of cash collateral, satisfactory to Issuing Bank (in its sole discretion) with the Borrower or such Lender to eliminate the Issuing Bank’s actual or potential Fronting Exposure (after giving effect to Section 4.03(c)(iii)) with respect to the Defaulting Lender arising from either the Letter of Credit then proposed to be issued or that Letter of Credit and all other obligations in respect of Letters of Credit as to which the Issuing Bank has actual or potential Fronting Exposure, as it may elect in its sole discretion.

(c)    Expiration Date. Each Letter of Credit shall expire at or prior to the close of business on the earlier of (i) the date twelve months (or such later date as may be requested by the Borrower and agreed to by the Issuing Bank in its sole discretion) after the date of the issuance of such Letter of Credit (or, in the case of any renewal or extension thereof, twelve months (or such later date as may be requested by the Borrower and agreed to by the Issuing Bank in its sole discretion) after such renewal or extension) and (ii) the date that is five Business Days prior to the Maturity Date (or such later date as consented to by the Issuing Bank in its sole discretion and provided that such Letter of Credit is cash collateralized or otherwise backstopped in such amounts and pursuant to such arrangements as are satisfactory to the Issuing Bank in its sole discretion).

(d)    Participations. By the issuance of a Letter of Credit (or an amendment to a Letter of Credit increasing the amount thereof) and without any further action on the part of the Issuing Bank or the Lenders, the Issuing Bank hereby grants to each Lender, and each Lender hereby acquires from the Issuing Bank, a participation in such Letter of Credit equal to such Lender’s Applicable Percentage of the aggregate amount available to be drawn under such Letter of Credit. In consideration and in furtherance of the foregoing, each Lender hereby absolutely and unconditionally agrees to pay to the Administrative Agent, for the account of the Issuing Bank, such Lender’s Applicable Percentage of each LC Disbursement made by the Issuing Bank and not reimbursed by the Borrower on the date due as provided in Section 2.08(e), or of any reimbursement payment required to be refunded to the Borrower for any reason, including after the Maturity Date. Each such payment shall be made without any offset, abatement, withholding or reduction whatsoever. Each Lender acknowledges and agrees that its obligation to acquire participations pursuant to this Section 2.08(d) in respect of Letters of Credit is absolute and unconditional and shall not be affected by any circumstance whatsoever, including any amendment, renewal or extension of any Letter of Credit or the occurrence and continuance of a Default, the existence of a Borrowing Base Deficiency or reduction or termination of the Commitments.

 

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(e)    Reimbursement. If the Issuing Bank shall make any LC Disbursement in respect of a Letter of Credit, the Borrower shall reimburse such LC Disbursement by paying to the Administrative Agent an amount equal to such LC Disbursement not later than 12:00 noon, Houston, Texas time, on the date that such LC Disbursement is made, if the Borrower shall have received notice of such LC Disbursement prior to 10:00 a.m., Houston, Texas time, on such date, or, if such notice has not been received by the Borrower prior to such time on such date, then not later than 12:00 noon, Houston, Texas time, on (i) the Business Day that the Borrower receives such notice, if such notice is received prior to 10:00 a.m., Houston, Texas time, on the day of receipt, or (ii) the Business Day immediately following the day that the Borrower receives such notice, if such notice is not received prior to such time on the day of receipt; provided that the Borrower shall, subject to the conditions to Borrowing set forth herein, be deemed to have requested, and the Borrower does hereby request under such circumstances, that such payment be financed with an ABR Borrowing in an equivalent amount and, to the extent so financed, the Borrower’s obligation to make such payment shall be discharged and replaced by the resulting ABR Borrowing. If the Borrower fails to make such payment when due, the Administrative Agent shall notify each Lender of the applicable LC Disbursement, the payment then due from the Borrower in respect thereof and such Lender’s Applicable Percentage thereof. Promptly following receipt of such notice, each Lender shall pay to the Administrative Agent its Applicable Percentage of the payment then due from the Borrower, in the same manner as provided in Section 2.05 with respect to Loans made by such Lender (and Section 2.05 shall apply, mutatis mutandis, to the payment obligations of the Lenders), and the Administrative Agent shall promptly pay to the Issuing Bank the amounts so received by it from the Lenders. Promptly following receipt by the Administrative Agent of any payment from the Borrower pursuant to this Section 2.08(e), the Administrative Agent shall distribute such payment to the Issuing Bank or, to the extent that Lenders have made payments pursuant to this Section 2.08(e) to reimburse the Issuing Bank, then to such Lenders and the Issuing Bank as their interests may appear. Any payment made by a Lender pursuant to this Section 2.08(e) to reimburse the Issuing Bank for any LC Disbursement (other than the funding of ABR Loans as contemplated above) shall not constitute a Loan and shall not relieve the Borrower of its obligation to reimburse such LC Disbursement.

(f)    Obligations Absolute. The Borrower’s obligation to reimburse LC Disbursements as provided in Section 2.08(e) shall be absolute, unconditional and irrevocable, and shall be performed strictly in accordance with the terms of this Agreement under any and all circumstances whatsoever and irrespective of (i) any lack of validity or enforceability of any Letter of Credit, any Letter of Credit Agreement or this Agreement, or any term or provision therein, (ii) any draft or other document presented under a Letter of Credit proving to be forged, fraudulent or invalid in any respect or any statement therein being untrue or inaccurate in any respect, (iii) payment by the Issuing Bank under a Letter of Credit against presentation of a draft or other document that does not comply with the terms of such Letter of Credit or any Letter of Credit Agreement, or (iv) any other event or circumstance whatsoever, whether or not similar to any of the foregoing, that might, but for the provisions of this Section 2.08(f), constitute a legal or equitable discharge of, or provide a right of setoff against, the Borrower’s obligations hereunder. Neither the Administrative Agent, the Lenders nor the Issuing Bank, nor any of their Related Parties shall have any liability or responsibility by reason of or in connection with the issuance or transfer of any Letter of Credit or any payment or failure to make any payment thereunder (irrespective of any of the circumstances referred to in the preceding sentence), or any error, omission, interruption, loss or delay in transmission or delivery of any draft, notice or other

 

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communication under or relating to any Letter of Credit (including any document required to make a drawing thereunder), any error in interpretation of technical terms, any error in translation or any consequence arising from causes beyond the control of the Issuing Bank; provided that the foregoing shall not be construed to excuse the Issuing Bank from liability to the Borrower to the extent of any direct damages (as opposed to special, indirect, consequential or punitive damages, claims in respect of which are hereby waived by the Borrower to the extent permitted by applicable law) suffered by the Borrower that are caused by the Issuing Bank’s failure to exercise care when determining whether drafts and other documents presented under a Letter of Credit comply with the terms thereof. The parties hereto expressly agree that, in the absence of gross negligence, or willful misconduct on the part of the Issuing Bank (as finally determined by a court of competent jurisdiction), the Issuing Bank shall be deemed to have exercised all requisite care in each such determination. In furtherance of the foregoing and without limiting the generality thereof, the parties agree that, with respect to documents presented which appear on their face to be in substantial compliance with the terms of a Letter of Credit, the Issuing Bank may, in its sole discretion, either accept and make payment upon such documents without responsibility for further investigation, regardless of any notice or information to the contrary, or refuse to accept and make payment upon such documents if such documents are not in strict compliance with the terms of such Letter of Credit.

(g)    Disbursement Procedures. The Issuing Bank shall, promptly following its receipt thereof, examine all documents purporting to represent a demand for payment under a Letter of Credit. The Issuing Bank shall promptly notify the Administrative Agent and the Borrower by telephone (confirmed by facsimile or electronic communication) of such demand for payment and whether the Issuing Bank has made or will make an LC Disbursement thereunder; provided that any failure to give or delay in giving such notice shall not relieve the Borrower of its obligation to reimburse the Issuing Bank and the Lenders with respect to any such LC Disbursement.

(h)    Interim Interest. If the Issuing Bank shall make any LC Disbursement, then, until the Borrower shall have reimbursed the Issuing Bank for such LC Disbursement (either with its own funds or a Borrowing under Section 2.08(e)), the unpaid amount thereof shall bear interest, for each day from and including the date such LC Disbursement is made to but excluding the date that the Borrower reimburses such LC Disbursement, at the rate per annum then applicable to ABR Loans. Interest accrued pursuant to this Section 2.08(h) shall be for the account of the Issuing Bank, except that interest accrued on and after the date of payment by any Lender pursuant to Section 2.08(e) to reimburse the Issuing Bank shall be for the account of such Lender to the extent of such payment.

(i)    Replacement and Resignation of the Issuing Bank.

(i)    The Issuing Bank may be replaced at any time by written agreement among the Borrower, the Administrative Agent, the replaced Issuing Bank and the successor Issuing Bank. The Administrative Agent shall notify the Lenders of any such replacement of the Issuing Bank. At the time any such replacement shall become effective, the Borrower shall pay all unpaid fees accrued for the account of the replaced Issuing Bank pursuant to Section 3.05(b). From and after the effective date of any such replacement, (A) the successor Issuing Bank shall have all the rights and obligations of the Issuing Bank under this Agreement with respect to Letters of

 

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Credit to be issued thereafter and (B) references herein to the term “Issuing Bank” shall be deemed to refer to such successor or to any previous Issuing Bank, or to such successor and all previous Issuing Bank, as the context shall require. After the replacement of the Issuing Bank hereunder, the replaced Issuing Bank shall remain a party hereto and shall continue to have all the rights and obligations of the Issuing Bank under this Agreement with respect to Letters of Credit issued by it prior to such replacement, but shall not be required to issue additional Letters of Credit or extend or otherwise amend any existing Letter of Credit.

(ii)    Subject to the appointment and acceptance of a successor Issuing Bank, the Issuing Bank may resign as the Issuing Bank at any time upon thirty days’ prior written notice to the Administrative Agent, the Borrower and the Lenders (or such shorter period of time as may be acceptable to the Issuing Bank, the Administrative Agent and the Borrower), in which case, the resigning Issuing Bank shall be replaced in accordance with Section 2.08(i)(i).

(j)    Cash Collateralization. If (i) any Event of Default shall occur and be continuing and the Borrower receives notice from the Administrative Agent or the Majority Lenders demanding that the Borrower cash collateralize, or otherwise backstop in such amounts and pursuant to such arrangements as are satisfactory to the Issuing Bank in its sole discretion, the outstanding LC Exposure, (ii) the Borrower is required to cash collateralize, or backstop in such amounts and pursuant to such arrangements as are satisfactory to the Issuing Bank in its sole discretion, the excess attributable to an LC Exposure in connection with any prepayment pursuant to Section 3.04(c), or (iii) the Borrower is required to cash collateralize, or otherwise backstop in such amounts and pursuant to such arrangements as are satisfactory to the Issuing Bank in its sole discretion, a Defaulting Lender’s LC Exposure pursuant to Section 4.03(c)(iii)(B), then the Borrower shall either (x) pledge and deposit with or deliver to the Administrative Agent (as a first priority, perfected security interest), for the benefit of the Issuing Bank, at a location and pursuant to documentation in form and substance satisfactory to the Administrative Agent, an amount in cash in dollars equal to 102% of such LC Exposure or excess attributable to such LC Exposure, as the case may be, as of such date plus any accrued and unpaid interest thereon or (y) or otherwise backstop such LC Exposure or excess attributable to such LC Exposure, as the case may be, in such amounts and pursuant to such arrangements as are satisfactory to the Issuing Bank in its sole discretion; provided that the obligation to deposit such cash collateral or otherwise backstop shall become effective immediately, and such deposit shall become immediately due and payable, without demand or other notice of any kind, upon the occurrence of any Event of Default described in Section 10.01(h) or Section 10.01(i). The Borrower hereby grants to the Administrative Agent, for the benefit of the Issuing Bank, an exclusive first priority and continuing perfected security interest in and Lien on such account and all cash, checks, drafts, certificates and instruments, if any, from time to time deposited or held in such account, all deposits or wire transfers made thereto, any and all investments purchased with funds deposited in such account, all interest, dividends, cash, instruments, financial assets and other Property from time to time received, receivable or otherwise payable in respect of, or in exchange for, any or all of the foregoing, and all proceeds, products, accessions, rents, profits, income and benefits therefrom, and any substitutions and replacements therefor. The Borrower’s obligation to deposit amounts, or otherwise backstop in such amounts and pursuant to such arrangements as are satisfactory to the Issuing Bank in its sole discretion, pursuant to this Section 2.08(j), shall be absolute and unconditional, without regard to whether any beneficiary of any Letter of Credit has attempted to draw down all or a portion of such amount under the terms of a Letter of Credit, and, to the fullest

 

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extent permitted by applicable law, shall not be subject to any defense or be affected by a right of set-off, counterclaim or recoupment which the Borrower or any Subsidiary may now or hereafter have against any such beneficiary, the Issuing Bank, the Administrative Agent, the Lenders or any other Person for any reason whatsoever. Such deposit (if applicable) shall be held as collateral securing the payment and performance of the Borrower’s and the Guarantors’ obligations under this Agreement and the other Loan Documents. In addition, and without limiting the foregoing or Section 2.08(c), if any LC Exposure remain outstanding after the expiration date specified in Section 2.08(c), the Borrower shall either immediately (x) deposit into such account an amount in cash equal to 102% of such LC Exposure as of such date plus any accrued and unpaid interest thereon or (y) otherwise backstop in such amounts and pursuant to such arrangements as are satisfactory to the Issuing Bank in its sole discretion. The Administrative Agent shall have exclusive dominion and control, including the exclusive right of withdrawal, over such account, except that the Administrative Agent shall not invest any funds maintained in such account without the Borrower’s prior written consent (which shall not be unreasonably withheld, conditioned or delayed). Other than any interest earned on the investment of such deposits, which investments shall be made at the option and sole discretion of the Administrative Agent and at the Borrower’s risk and expense, such deposits shall not bear interest. Interest or profits, if any, on such investments shall accumulate in such account. Moneys in such account shall be applied by the Administrative Agent to reimburse the Issuing Bank for LC Disbursements for which it has not been reimbursed, and, to the extent not so applied, shall be held for the satisfaction of the reimbursement obligations of the Borrower for the LC Exposure at such time or, if the maturity of the Loans has been accelerated, be applied to satisfy other obligations of the Borrower and the Guarantors under this Agreement and the other Loan Documents. If the Borrower is required to provide an amount of cash collateral hereunder or otherwise backstop as a result of the occurrence of an Event of Default or pursuant to Section 4.03(c)(iii)(B) as a result of a Defaulting Lender, and the Borrower is not otherwise required to cash collateralize or otherwise backstop the excess attributable to an LC Exposure in connection with any prepayment pursuant to Section 3.04(c), then such amount (to the extent not applied as aforesaid) shall be returned to the Borrower within three Business Days after all Events of Default have been cured or waived or the events giving rise to such cash collateralization or backstopping pursuant to Section 4.03(c)(iii)(B) have been satisfied or resolved.

(k)    Letters of Credit Issued for Account of Guarantors. Notwithstanding that a Letter of Credit issued or outstanding hereunder supports any obligations of, or is for the account of, a Guarantor, or states that a Guarantor is the “account party,” “applicant,” “customer,” “instructing party,” or the like of or for such Letter of Credit, and without derogating from any rights of the Issuing Bank (whether arising by contract, at law, in equity or otherwise) against such Guarantor in respect of such Letter of Credit, the Borrower (i) shall reimburse, indemnify and compensate the Issuing Bank hereunder for such Letter of Credit (including to reimburse any and all drawings thereunder) as if such Letter of Credit had been issued solely for the account of the Borrower and (ii) irrevocably waives any and all defenses that might otherwise be available to it as a guarantor or surety of any or all of the obligations of such Guarantor in respect of such Letter of Credit. The Borrower hereby acknowledges that the issuance of such Letters of Credit for its Restricted Subsidiaries inures to the benefit of the Borrower, and that the Borrower’s business derives substantial benefits from the businesses of such Guarantors.

 

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(l)    Applicability of ISP and UCP. Unless otherwise expressly agreed by the Issuing Bank and the Borrower when a Letter of Credit is issued by it, (i) the rules of the ISP shall apply to each standby Letter of Credit and (ii) the rules of the UCP shall apply to each commercial Letter of Credit. Notwithstanding the foregoing, the Issuing Bank shall not be responsible to the Borrower for, and the Issuing Bank’s rights and remedies against the Borrower shall not be impaired by, any action or inaction of the Issuing Bank required or permitted under any law, order, or practice that is required or permitted to be applied to any Letter of Credit or this Agreement, including the law or any order of a jurisdiction where the Issuing Bank or the beneficiary is located, the practice stated in the ISP or UCP, as applicable, or in the decisions, opinions, practice statements, or official commentary of the ICC Banking Commission, the Bankers Association for Finance and Trade – International Financial Services Association (BAFT-IFSA), or the Institute of International Banking Law & Practice, whether or not any Letter of Credit chooses such law or practice.

ARTICLE III

PAYMENTS OF PRINCIPAL AND INTEREST; PREPAYMENTS; FEES

Section 3.01    Repayment of Loans. The Borrower hereby unconditionally promises to pay to the Administrative Agent for the account of each Lender the then unpaid principal amount of each Loan on the Termination Date.

Section 3.02    Interest.

(a)    ABR Loans. The Loans comprising each ABR Borrowing shall bear interest at the Alternate Base Rate plus the Applicable Margin, but in no event to exceed the Highest Lawful Rate.

(b)    Term SOFR Loans. The Loans comprising each Term SOFR Borrowing shall bear interest at Term SOFR for the Interest Period in effect for such Borrowing plus the Applicable Margin, but in no event to exceed the Highest Lawful Rate.

(c)    Post-Default Rate. Notwithstanding the foregoing, (i) if an Event of Default under Section 10.01(h) or (i) has occurred and is continuing, (ii) if any principal of or interest on any Loan or any fee or other amount payable by the Borrower or any Guarantor hereunder or under any other Loan Document is not paid when due, whether at stated maturity, upon acceleration or otherwise, and to the extent that such failure to pay constitutes an Event of Default under Section 10.01(a) or (b), or (iii) at the election of the Majority Lenders, if an Event of Default (other than with respect to Section 10.01(a), (b), (h) or (i)) has occurred and is continuing, then all Loans outstanding (in the case of clauses (i) and (iii)), and such overdue amount (in the case of clause (ii)), shall bear interest, after as well as before judgment, at a rate per annum equal to two percent (2%) plus the rate that would otherwise be applicable thereto pursuant to the foregoing provisions of this Section 3.02, but in no event to exceed the Highest Lawful Rate.

(d)    Interest Payment Dates. Accrued interest on each Loan shall be payable in arrears on each Interest Payment Date for such Loan and on the Termination Date; provided that (i) interest accrued pursuant to Section 3.02(c) shall be payable on demand, (ii) in the event of any repayment or prepayment of any Loan (other than an optional prepayment of an ABR Loan prior

 

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to the Termination Date), accrued interest on the principal amount repaid or prepaid shall be payable on the date of such repayment or prepayment, and (iii) in the event of any conversion of any Term SOFR Loan prior to the end of the current Interest Period therefor, accrued interest on such Loan shall be payable on the effective date of such conversion.

(e)    Interest Rate Computations. All interest hereunder shall be computed on the basis of a year of 360 days, unless such computation would exceed the Highest Lawful Rate, in which case interest shall be computed on the basis of a year of 365 days (or 366 days in a leap year), except that interest computed by reference to the Alternate Base Rate at times when the Alternate Base Rate is based on the Prime Rate shall be computed on the basis of a year of 365 days (or 366 days in a leap year), and in each case shall be payable for the actual number of days elapsed (including the first day but excluding the last day). The applicable Alternate Base Rate or Adjusted Term SOFR shall be determined by the Administrative Agent, and such determination shall be conclusive absent manifest error, and shall be binding upon the parties hereto.

(f)    Term SOFR Conforming Changes. With respect to SOFR or Term SOFR, the Administrative Agent will have the right to make Conforming Changes from time to time and, notwithstanding anything to the contrary herein or in any other Loan Document, any amendments implementing such Conforming Changes will become effective without any further action or consent of any other party to this Agreement or any other Loan Document; provided that, with respect to any such amendment effected, the Administrative Agent shall post each such amendment implementing such Conforming Changes to the Borrower and the Lenders reasonably promptly after such amendment becomes effective.

Section 3.03    Inability to Determine Rates.

(a)    Temporary Unavailability of Term SOFR. If in connection with any request for a Term SOFR Loan or a conversion of ABR Loans to Term SOFR Loans or a continuation of any of such Loans, as applicable, (i) the Administrative Agent determines (which determination shall be conclusive absent manifest error) that (A) no Successor Rate has been determined in accordance with Section 3.03(b), and the circumstances under clause (i) of Section 3.03(b) or the Scheduled Unavailability Date has occurred, or (B) adequate and reasonable means do not otherwise exist for determining Term SOFR for any requested Interest Period with respect to a proposed Term SOFR Loan or in connection with an existing or proposed ABR Loan, or (ii) the Administrative Agent or the Majority Lenders determine that for any reason the Term SOFR for any requested Interest Period with respect to a proposed Loan does not adequately and fairly reflect the cost to such Lenders of funding such Loan, the Administrative Agent will promptly so notify the Borrower and each Lender.

Thereafter, (x) the obligation of the Lenders to make or maintain Term SOFR Loans or to convert ABR Loans to Term SOFR Loans, shall be suspended (to the extent of the affected Term SOFR Loans or Interest Periods), and (y) in the event of a determination described in the preceding sentence with respect to the Term SOFR component of the Alternate Base Rate, the utilization of the Term SOFR component in determining the Alternate Base Rate shall be suspended, in each case until the Administrative Agent (or, in the case of a determination by the Majority Lenders described in clause (ii) of this Section 3.03(a), until the Administrative Agent upon instruction of the Majority Lenders) revokes such notice.

 

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Upon receipt of such notice, (i) the Borrower may revoke any pending request for a Borrowing of, or conversion to, or continuation of Term SOFR Loans (to the extent of the affected Term SOFR Loans or Interest Periods) or, failing that, will be deemed to have converted such request into a request for a Borrowing of ABR Loans in the amount specified therein and (ii) any outstanding Term SOFR, Loans shall be deemed to have been converted to ABR Loans immediately at the end of their respective applicable Interest Period.

(b)    Replacement of Term SOFR or Successor Rate. Notwithstanding anything to the contrary in this Agreement or any other Loan Documents, if the Administrative Agent determines (which determination shall be conclusive absent manifest error), or the Borrower or the Majority Lenders notify the Administrative Agent (with, in the case of the Majority Lenders, a copy to the Borrower) that the Borrower or the Majority Lenders (as applicable) have determined, that:

(i)    adequate and reasonable means do not exist for ascertaining one month, three month and six month interest periods of Term SOFR, including, without limitation, because the Term SOFR Screen Rate is not available or published on a current basis and such circumstances are unlikely to be temporary; or

(ii)    CME or any successor administrator of the Term SOFR Screen Rate or a Governmental Authority having jurisdiction over the Administrative Agent or such administrator with respect to its publication of Term SOFR, in each case acting in such capacity, has made a public statement identifying a specific date after which one month, three month and six month interest periods of Term SOFR or the Term SOFR Screen Rate shall or will no longer be made available, or permitted to be used for determining the interest rate of U.S. dollar denominated syndicated loans, or shall or will otherwise cease, provided that, at the time of such statement, there is no successor administrator that is satisfactory to the Administrative Agent, that will continue to provide such interest periods of Term SOFR after such specific date (the latest date on which one month, three month and six month interest periods of Term SOFR or the Term SOFR, Screen Rate are no longer available permanently or indefinitely, the “Scheduled Unavailability Date”);

then, on a date and time determined by the Administrative Agent (any such date, the “Term SOFR Replacement Date”), which date shall be at the end of an Interest Period or on the relevant interest payment date, as applicable, for interest calculated and, solely with respect to clause (ii) above, no later than the Scheduled Unavailability Date, Term SOFR will be replaced hereunder and under any Loan Document with Daily Simple SOFR plus the SOFR Adjustment for any payment period for interest calculated that can be determined by the Administrative Agent, in each case, without any amendment to, or further action or consent of any other party to, this Agreement or any other Loan Document (the “Successor Rate”).

If the Successor Rate is Daily Simple SOFR plus the SOFR Adjustment, all interest payments will be payable on a quarterly basis.

Notwithstanding anything to the contrary herein, (x) if the Administrative Agent determines that Daily Simple SOFR is not available on or prior to the Term SOFR Replacement Date, or (y) if the events or circumstances of the type described in Section 3.03(b)(i) or (ii) have occurred with

 

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respect to the Successor Rate then in effect, then in each case, the Administrative Agent and the Borrower may amend this Agreement solely for the purpose of replacing Term SOFR or any then current Successor Rate in accordance with this Section 3.03 at the end of any Interest Period, relevant interest payment date or payment period for interest calculated, as applicable, with an alternative benchmark rate giving due consideration to any evolving or then existing convention for similar U.S. dollar denominated credit facilities syndicated and agented in the United States for such alternative benchmark, and, in each case, including any mathematical or other adjustments to such benchmark giving due consideration to any evolving or then existing convention for similar U.S. dollar denominated credit facilities syndicated and agented in the United States for such benchmark, which adjustment or method for calculating such adjustment shall be published on an information service as selected by the Administrative Agent from time to time in its reasonable discretion and may be periodically updated. For the avoidance of doubt, any such proposed rate and adjustments. shall constitute a “Successor Rate”. Any such amendment shall become effective at 5:00 p.m. on the fifth Business Day after the Administrative Agent shall have posted such proposed amendment to all Lenders and the Borrower unless, prior to such time, Lenders comprising the Majority Lenders have delivered to the Administrative Agent written notice that such Majority Lenders object to such amendment.

The Administrative Agent will promptly (in one or more notices) notify the Borrower and each Lender of the implementation of any Successor Rate.

Any Successor Rate shall be applied in a manner consistent with market practice; provided that to the extent such market practice is not administratively feasible for the Administrative Agent, such Successor Rate shall be applied in a manner as otherwise reasonably determined by the Administrative Agent.

Notwithstanding anything else herein, if at any time any Successor Rate as so determined would otherwise be less than the Floor, the Successor Rate will be deemed to be the Floor for the purposes of this Agreement and the other Loan Documents.

In connection with the implementation of a Successor Rate, the Administrative Agent will have the right to make Conforming Changes from time to time and, notwithstanding anything to the contrary herein or in any other Loan Document, any amendments implementing such Conforming Changes will become effective without any further action or consent of any other party to this Agreement; provided that, with respect to any such amendment effected, the Administrative Agent shall post each such amendment implementing such Conforming Changes to the Borrower and the Lenders reasonably promptly after such amendment becomes effective.

For purposes of this Section 3.03, those Lenders that either have not made, or do not have an obligation under this Agreement to make, the relevant Loans in Dollars shall be excluded from any determination of Majority Lenders.

Section 3.04    Prepayments.

(a)    Optional Prepayments. The Borrower shall have the right at any time and from time to time to prepay, without premium or penalty (except with respect to any amounts due under Section 5.02), any Borrowing in whole or in part, subject to prior notice in accordance with Section 3.04(b).

 

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(b)    Notice and Terms of Optional Prepayment. The Borrower shall notify the Administrative Agent by telephone (confirmed by facsimile or electronic communication) of any prepayment hereunder (i) in the case of prepayment of a Term SOFR Borrowing, not later than 12:00 noon, Houston, Texas time, two Business Days before the date of prepayment, or (ii) in the case of prepayment of an ABR Borrowing, not later than 12:00 noon, Houston, Texas time, on the date of prepayment. Each such notice shall be confirmed promptly by hand delivery or email to the Administrative Agent of a written notice of prepayment signed by a Responsible Officer of the Borrower. Each such notice shall be irrevocable and shall specify the prepayment date and the principal amount of each Borrowing or portion thereof to be prepaid; provided that, if a notice of prepayment is given in connection with a conditional notice of termination of the Commitments as contemplated by Section 2.06(b), then such notice of prepayment may be revoked if such notice of termination is revoked in accordance with Section 2.06(b); provided further, that, subject to Section 5.02, the Borrower may rescind any notice of prepayment if such prepayment would have resulted from a refinancing of all or a material part of the Obligations, which refinancing shall not be consummated or shall otherwise be delayed. Promptly following receipt of any such notice relating to a Borrowing, the Administrative Agent shall advise the Lenders of the contents thereof. Each partial prepayment of any Borrowing shall be in an amount that would be permitted in the case of an advance of a Borrowing of the same Type as provided in Section 2.02. Each prepayment of a Borrowing shall be applied ratably to the Loans included in the prepaid Borrowing. Prepayments shall be accompanied by accrued interest to the extent required by Section 3.02 and any payments to the extent required by Section 5.02.

(c)    Mandatory Prepayments.

(i)    If, after giving effect to any termination or reduction of the Aggregate Maximum Credit Amounts pursuant to Section 2.06(b), the total Revolving Credit Exposures exceeds the total Commitments, then the Borrower shall (A) prepay the Borrowings on the date of such termination or reduction in an aggregate principal amount equal to such excess, and (B) if any excess remains after prepaying all of the Borrowings as a result of an LC Exposure, cash collateralize or otherwise backstop such excess as provided in Section 2.08(j).

(ii)    Upon any redetermination or adjustment to the amount of the Borrowing Base in accordance with Section 2.07 (other than pursuant to Section 2.07(e) or Section 2.07(f)) or Section 8.13(c), if the total Revolving Credit Exposures exceeds the redetermined or adjusted Borrowing Base, then after receiving a New Borrowing Base Notice in accordance with Section 2.07(d) or a notice of adjustment pursuant to Section 8.13(c), as the case may be (the date of receipt of any such notice, the “Deficiency Notification Date”), the Borrower shall (i) deliver, within 10 Business Days after the Deficiency Notification Date, written notice to the Administrative Agent indicating the Borrower’s election to: (A) prepay the Borrowings in an aggregate principal amount equal to such Borrowing Base Deficiency (and to the extent that any excess remains after prepaying all of the Borrowings as a result of an LC Exposure, cash collateralize or otherwise backstop such excess as provided in Section 2.08(j)) on or before the 30th day following the Deficiency Notification Date; (B) prepay the Borrowings in six consecutive equal monthly installments, the first installment being due and payable on the 30th day following

 

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the Deficiency Notification Date and each subsequent installment being due and payable on the same day in each of the subsequent calendar months, with each payment being equal to one-sixth (1/6th) of such Borrowing Base Deficiency, so that such Borrowing Base Deficiency is reduced to zero on or before such sixth prepayment date; (C) identify, within thirty (30) days following the Deficiency Notification Date, to the Administrative Agent additional Oil and Gas Properties with Borrowing Base value acceptable to the Required Lenders in their sole discretion not evaluated in the most recently delivered Reserve Report sufficient to cure the Borrowing Base Deficiency and, to the extent the mortgage requirement set forth in Section 8.14(a) has not been complied with on a pro forma basis including such additional Oil and Gas Properties, grant to the Administrative Agent a first-priority Lien (subject to Excepted Liens) on such additional Oil and Gas Properties sufficient to satisfy such requirement on a pro forma basis; provided that in no event may the Borrower elect the option specified in this clause (C) if fewer than ninety (90) days remain until the Maturity Date; or (D) combine the options provided in clauses (A), (B) and/or (C) above, and also indicating the amount to be prepaid and the amount to be provided as additional Collateral, and (ii) make such payment and deliver such additional Collateral within the time required under clauses (A), (B) and/or (C) above; provided that, notwithstanding the options set forth above, (x) in all cases, the Borrowing Base Deficiency must be eliminated on or prior to the Termination Date, (y) after making an election described above, with the consent of the Administrative Agent, the Borrower may make additional payments or identify additional Oil and Gas Properties (as contemplated by clause (C) without regard to the timeframe set forth therein) in order to accelerate the cure of the Borrowing Base Deficiency and (z) if the Borrowing Base Deficiency is reduced to zero through any combination of the options set forth herein or through a subsequent Borrowing Base increase, the Borrower’s obligations to cure the previously existing Borrowing Base Deficiency shall cease and the Borrower shall have no obligation to make additional scheduled prepayments in respect of such Borrowing Base Deficiency. The Borrower shall provide to the Administrative Agent, within ten (10) Business Days following its receipt of the New Borrowing Base Notice in accordance with Section 2.07(d) or the date the adjustment occurs pursuant to Section 8.13(c), as applicable, an irrevocable written notice indicating which of the options specified in clauses (A), (B), (C) or (D) the Borrower elects to take in order to eliminate the Borrowing Base Deficiency. Such notice shall be irrevocable and, in the event the Borrower fails to provide such written notice to the Administrative Agent within the ten (10) Business Day period referred to above, the Borrower shall be deemed to have irrevocably elected the option set forth in clause (B) above. The failure of the Borrower to comply with any of the options elected (including any deemed election) pursuant to the provisions of this Section 3.04(c)(ii) and specified in such notice (or relating to such deemed election) shall constitute an Event of Default.

(iii)    Upon any adjustment to the Borrowing Base pursuant to Section 2.07(e) or Section 2.07(f), if the total Revolving Credit Exposures exceeds the Borrowing Base as adjusted, then the Borrower shall (A) prepay the Borrowings in an aggregate principal amount equal to such excess, and (B) if any excess remains after prepaying all of the Borrowings as a result of an LC Exposure, cash collateralize or otherwise backstop such excess as provided in Section 2.08(j). The Borrower shall be obligated to make such prepayment and/or cash collateralize or otherwise backstop such excess on the date the adjustment occurs; provided that all payments required to be made pursuant to this Section 3.04(c)(iii) must be made on or prior to the Termination Date.

 

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(iv)    Unless the Borrower notifies the Administrative Agent in writing of an alternate application to the Borrowings then outstanding, each prepayment of Borrowings pursuant to this Section 3.04(c) shall be applied, first, ratably to any ABR Borrowings then outstanding, and, second, to any Term SOFR Borrowings then outstanding, and if more than one Term SOFR Borrowing is then outstanding, to each such Term SOFR Borrowing in order of priority beginning with the Term SOFR Borrowing with the least number of days remaining in the Interest Period applicable thereto and ending with the Term SOFR Borrowing with the most number of days remaining in the Interest Period applicable thereto.

(v)    Each prepayment of Borrowings pursuant to this Section 3.04(c) shall be applied ratably to the Loans included in the prepaid Borrowings. Prepayments pursuant to this Section 3.04(c) shall be accompanied by accrued interest to the extent required by Section 3.02.

(vi)    Mandatory Prepayment with Excess Cash. If, as of the last day of any calendar month (whether or not such day is a Business Day) (the “Excess Cash Test Date”), the Loan Parties have Excess Cash as of the end of such Excess Cash Test Date (whether or not such Excess Cash Test Date is a Business Day), the Borrower shall, within three (3) Business Days of such Excess Cash Test Date, prepay Borrowings in an amount equal to the lesser of (i) the amount of such Excess Cash as of the end of such Excess Cash Test Date (whether or not such Excess Cash Test Date is a Business Day) and (ii) the amount of Borrowings as of the end of such Excess Cash Test Date (whether or not such Excess Cash Test Date is a Business Day); provided that if any such Excess Cash remains after such Borrowings are fully prepaid, the Borrower shall apply such remaining Excess Cash to cash collateralize or otherwise backstop any LC Exposure with such remaining Excess Cash as provided in Section 2.08(j).

(d)    No Premium or Penalty. Prepayments permitted or required under this Section 3.04 shall be without premium or penalty, except as required under Section 5.02.

Section 3.05    Fees.

(a)    Commitment Fees. The Borrower agrees to pay to the Administrative Agent for the account of each Lender a commitment fee, which shall accrue at the applicable Commitment Fee Rate on the actual daily amount of the unused amount of the Commitment of such Lender during the period from and including the Effective Date to but excluding the Termination Date. Accrued commitment fees shall be payable in arrears on the last day of March, June, September and December of each year and on the Termination Date, commencing on the first such date to occur after the Effective Date. All commitment fees shall be computed on the basis of a year of 360 days, unless such computation would exceed the Highest Lawful Rate, in which case such commitment fees shall be computed on the basis of a year of 365 days (or 366 days in a leap year), and shall be payable for the actual number of days elapsed (including the first day but excluding the last day).

(b)    Letter of Credit Fees. The Borrower agrees to pay (i) to the Administrative Agent for the account of each Lender a participation fee with respect to its participations in Letters of Credit, which shall accrue at the same Applicable Margin used to determine the interest rate applicable to Term SOFR Loans on the actual daily amount of such Lender’s LC Exposure

 

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(excluding any portion thereof attributable to unreimbursed LC Disbursements) during the period from and including the Effective Date to but excluding the later of the date on which such Lender’s Commitment terminates and the date on which such Lender ceases to have any LC Exposure, (ii) to the Issuing Bank a fronting fee, which shall accrue at the rate of 0.125% per annum on the actual daily amount of the LC Exposure with respect to Letters of Credit issued by it (excluding any portion thereof attributable to unreimbursed LC Disbursements) during the period from and including the Effective Date to but excluding the later of the date of termination of the Commitments and the date on which there ceases to be any LC Exposure; provided that in no event shall such fee be less than $500 during any quarter, and (iii) to the Issuing Bank, for its own account, its standard fees with respect to the issuance, amendment, renewal or extension of any Letter of Credit or processing of drawings thereunder. Participation fees and fronting fees accrued through and including the last day of March, June, September and December of each year shall be payable on the third Business Day following such last day, commencing on the first such date to occur after the Effective Date; provided that all such unpaid fees shall be payable on the Termination Date and any such fees accruing after the Termination Date shall be payable on demand. During the continuation of an Event of Default, to the extent the Majority Lenders have elected to charge default rate interest pursuant to Section 3.02(c)(ii), the fees payable pursuant to this Section 3.05(b) shall increase by 2.00% per annum over the then-applicable rate. Any other fees payable to the Issuing Bank pursuant to this Section 3.05(b) shall be payable within 10 days after demand. All participation fees and fronting fees shall be computed on the basis of a year of 360 days, unless such computation would exceed the Highest Lawful Rate, in which case such fees shall be computed on the basis of a year of 365 days (or 366 days in a leap year), and shall be payable for the actual number of days elapsed (including the first day but excluding the last day).

(c)    Administrative Agent Fees. The Borrower agrees to pay to the Administrative Agent, for its own account, fees payable in the amounts and at the times set forth in the Fee Letters.

ARTICLE IV

PAYMENTS; PRO RATA TREATMENT; SHARING OF SET-OFFS

Section 4.01    Payments Generally; Pro Rata Treatment; Sharing of Set-offs.

(a)    Payments by the Borrower. The Borrower shall make each payment required to be made by it hereunder (whether of principal, interest, fees or reimbursement of LC Disbursements, or of amounts payable under Section 5.01, Section 5.02, Section 5.03 or otherwise) prior to 12:00 noon, Houston, Texas time, on the date when due, in immediately available funds, without condition or deduction for any counterclaim, defense, recoupment or setoff. Fees, once paid, shall be fully earned and shall not be refundable under any circumstances absent manifest error. Any amounts received after such time on any date may, in the discretion of the Administrative Agent, be deemed to have been received on the next succeeding Business Day for purposes of calculating interest thereon. All such payments shall be made to the Administrative Agent at its offices specified in Section 12.01, except payments to be made directly to the Issuing Bank as expressly provided herein and except that payments pursuant to Section 5.01, Section 5.02, Section 5.03 and Section 12.03 shall be made directly to the Persons entitled thereto. The Administrative Agent shall distribute any such payments received by it for the account of any other Person to the appropriate recipient promptly following receipt thereof. If any payment

 

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hereunder shall be due on a day that is not a Business Day, the date for payment shall be extended to the next succeeding Business Day, and, in the case of any payment accruing interest, interest thereon shall be payable for the period of such extension. All payments hereunder shall be made in dollars.

(b)    Application of Insufficient Payments. If at any time insufficient funds are received by and available to the Administrative Agent to pay fully all amounts of principal, unreimbursed LC Disbursements, interest and fees then due hereunder, such funds shall be applied (i) first, towards payment of interest and fees then due hereunder, ratably among the parties entitled thereto in accordance with the amounts of interest and fees then due to such parties, and (ii) second, towards payment of principal and unreimbursed LC Disbursements then due hereunder, ratably among the parties entitled thereto in accordance with the amounts of principal and unreimbursed LC Disbursements then due to such parties.

(c)    Sharing of Payments by Lenders. If any Lender shall, by exercising any right of setoff or counterclaim or otherwise, obtain payment in respect of (a) Obligations due and payable to such Lender hereunder and under the other Loan Documents at such time in excess of its ratable share (according to the proportion of (i) the amount of such Obligations due and payable to such Lender at such time to (ii) the aggregate amount of the Obligations due and payable to all Lenders hereunder and under the other Loan Documents at such time) of payments on account of the Obligations due and payable to all Lenders hereunder and under the other Loan Documents at such time obtained by all the Lenders at such time or (b) Obligations owing (but not due and payable) to such Lender hereunder and under the other Loan Documents at such time in excess of its ratable share (according to the proportion of (i) the amount of such Obligations owing (but not due and payable) to such Lender at such time to (ii) the aggregate amount of the Obligations owing (but not due and payable) to all Lenders hereunder and under the other Loan Documents at such time) of payment on account of the Obligations owing (but not due and payable) to all Lenders hereunder and under the other Loan Documents at such time obtained by all of the Lenders at such time then the Lender receiving such greater proportion shall (a) notify the Administrative Agent of such fact, and (b) purchase (for cash at face value) participations in the Loans and subparticipations in LC Disbursements of the other Lenders, or make such other adjustments as shall be equitable, so that the benefit of all such payments shall be shared by the Lenders ratably in accordance with the aggregate amount of Obligations then due and payable to the Lenders or owing (but not due and payable) to the Lenders, as the case may be, provided that:

(i)    if any such participations or subparticipations are purchased and all or any portion of the payment giving rise thereto is recovered, such participations or subparticipations shall be rescinded and the purchase price restored to the extent of such recovery, without interest; and

(ii)    the provisions of this Section 4.01(c) shall not be construed to apply to (A) any payment made by or on behalf of the Borrower pursuant to and in accordance with the express terms of this Agreement (including the application of funds arising from the existence of a Defaulting Lender), (B) the application of cash collateral provided for in Section 2.08(j), or (C) any payment obtained by a Lender as consideration for the assignment of or sale of a participation in any of its Loans or subparticipations in LC Disbursements to any assignee or participant, other than an assignment to the Borrower or any Affiliate thereof (as to which the provisions of this Section 4.01(c) shall apply).

 

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(d)    The Borrower consents to the foregoing and agrees, to the extent it may effectively do so under applicable law, that any Lender acquiring a participation pursuant to the foregoing arrangements may exercise against the Borrower rights of setoff and counterclaim with respect to such participation as fully as if such Lender were a direct creditor of the Borrower in the amount of such participation.

Section 4.02    Presumption of Payment by the Borrower. Unless the Administrative Agent shall have received notice from the Borrower prior to the date on which any payment is due to the Administrative Agent for the account of the Lenders or the Issuing Bank that the Borrower will not make such payment, the Administrative Agent may assume that the Borrower has made such payment on such date in accordance herewith and may, in reliance upon such assumption, distribute to the Lenders or the Issuing Bank, as the case may be, the amount due. In such event, if the Borrower has not in fact made such payment, then each of the Lenders or the Issuing Bank, as the case may be, severally agrees to repay to the Administrative Agent forthwith on demand the amount so distributed to such Lender or Issuing Bank in immediately available funds with interest thereon, for each day from and including the date such amount is distributed to it to but excluding the date of payment to the Administrative Agent, at the greater of the Federal Funds Rate and a rate determined by the Administrative Agent in accordance with banking industry rules on interbank compensation. A notice of the Administrative Agent to any Lender with respect to any amount owing under this Section 4.02 shall be conclusive, absent manifest error.

Section 4.03    Deductions by the Administrative Agent; Defaulting Lenders.

(a)    Certain Deductions by the Administrative Agent. If any Lender shall fail to make any payment required to be made by it pursuant to Section 2.05(a), Section 2.08(d), Section 2.08(e), Section 4.02, Section 5.03(f), Section 11.10 or Section 12.03(c), then the Administrative Agent may, in its sole discretion (notwithstanding any contrary provision hereof), (i) apply any amounts thereafter received by the Administrative Agent for the account of such Lender for the benefit of the Administrative Agent or the Issuing Bank to satisfy such Lender’s obligations to it under such Sections until all such unsatisfied obligations are fully paid, and/or (ii) hold any such amounts in a segregated account as cash collateral for, and application to, any future funding obligations of such Lender under any such Section, in the case of each of clauses (i) and (ii) above, in any order as determined by the Administrative Agent in its sole discretion.

(b)    Payments to Defaulting Lenders. If a Defaulting Lender (or a Lender who would be a Defaulting Lender but for the expiration of the relevant grace period) as a result of the exercise of a set-off shall have received a payment in respect of its Revolving Credit Exposure which results in its Revolving Credit Exposure being less than its Applicable Percentage of the aggregate Revolving Credit Exposures, then no payments will be made to such Defaulting Lender until such time as such Defaulting Lender shall have complied with Section 4.03(c) and all amounts due and owing to the Lenders have been equalized in accordance with each Lender’s respective pro rata share of the Obligations. Further, if at any time prior to the acceleration or maturity of the Loans, the Administrative Agent shall receive any payment in respect of principal of a Loan or a reimbursement of an LC Disbursement while one or more Defaulting Lenders shall be party to this

 

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Agreement, the Administrative Agent shall apply such payment first to the Borrowing(s) for which such Defaulting Lender(s) shall have failed to fund its pro rata share until such time as such Borrowing(s) are paid in full or each Lender (including each Defaulting Lender) is owed its Applicable Percentage of all Loans then outstanding. After acceleration or maturity of the Loans, subject to the first sentence of this Section 4.03(b), all principal will be paid ratably as provided in Section 10.02(c).

(c)    Defaulting Lenders. Notwithstanding any provision of this Agreement to the contrary, if any Lender becomes a Defaulting Lender, then the following provisions shall apply for so long as such Lender is a Defaulting Lender:

(i)    Fees shall cease to accrue on the unfunded portion of the Commitment of such Defaulting Lender pursuant to Section 3.05(a).

(ii)    The Commitment, the Maximum Credit Amount and the Revolving Credit Exposure of such Defaulting Lender shall not be included in determining whether the Required Lenders or the Majority Lenders have taken or may take any action hereunder (including any consent to any amendment or waiver pursuant to Section 12.02); provided that any waiver, amendment or modification requiring the consent of all Lenders or each affected Lender shall require the consent of such Defaulting Lender; and provided, further, that any redetermination or affirmation of the Borrowing Base shall occur without the participation of a Defaulting Lender, but the Commitment (i.e., the Applicable Percentage of the Borrowing Base of a Defaulting Lender) may not be increased without the consent of such Defaulting Lender; provided, that, subject to Section 12.19, no such reallocation will constitute a waiver or release of any claim the Borrower, the Administrative Agent, the Issuing Bank or any Lender may have against such Defaulting Lender or cause such Defaulting Lender to be a Non-Defaulting Lender.

(iii)    If any LC Exposure exists at the time a Lender becomes a Defaulting Lender then:

(A)    all or any part of the LC Exposure of such Defaulting Lender shall be reallocated among the Non-Defaulting Lenders in accordance with their respective Applicable Percentages (for the purposes of such reallocation the Defaulting Lender’s Commitment shall be disregarded in determining the Non-Defaulting Lender’s Applicable Percentage) but only to the extent (1) the sum of all Non-Defaulting Lenders’ Revolving Credit Exposures plus such Defaulting Lender’s LC Exposure does not exceed the total of all Non-Defaulting Lenders’ Commitments and (2) the sum of each Non-Defaulting Lender’s Revolving Credit Exposure plus its reallocated share of such Defaulting Lender’s LC Exposure does not exceed such Non-Defaulting Lender’s Commitment; provided further that, subject to Section 12.19, no reallocation hereunder shall constitute a waiver or release of any claim of any party hereunder against a Defaulting Lender arising from that Lender having become a Defaulting Lender, including any claim of a Non-Defaulting Lender as a result of such Non-Defaulting Lender’s increased exposure following such reallocation;

(B)    if the reallocation described in clause (A) above cannot, or can only partially, be effected, then the Borrower shall within one Business Day following notice by the Administrative Agent cash collateralize for the benefit of the Issuing Bank only the

 

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Borrower’s obligations corresponding to such Defaulting Lender’s LC Exposure (after giving effect to any partial reallocation pursuant to clause (A) above), or otherwise backstop such LC Exposure in such amounts and pursuant to such arrangements as are satisfactory to the Issuing Bank in its sole discretion, in accordance with the procedures set forth in Section 2.08(j) for so long as such LC Exposure is outstanding and the relevant Defaulting Lender remains a Defaulting Lender;

(C)    if the Borrower cash collateralizes or backstops any portion of such Defaulting Lender’s LC Exposure pursuant to clause (B) above, then the Borrower shall not be required to pay any fees to such Defaulting Lender pursuant to Section 3.05(b) with respect to such Defaulting Lender’s LC Exposure during the period such Defaulting Lender’s LC Exposure is cash collateralized or otherwise backstopped;

(D)    if the LC Exposure of the Non-Defaulting Lenders is reallocated pursuant to clause (A) above, then the fees payable to the Lenders pursuant to Section 3.05(a) and Section 3.05(b) shall be adjusted in accordance with such Non-Defaulting Lenders’ Applicable Percentages; and

(E)    if all or any portion of such Defaulting Lender’s LC Exposure is neither reallocated nor cash collateralized nor backstopped pursuant to clause (A) or (B) above, then, without prejudice to any rights or remedies of the Issuing Bank or any other Lender hereunder, all commitment fees that otherwise would have been payable to such Defaulting Lender (solely with respect to the portion of such Defaulting Lender’s Commitment that was utilized by such LC Exposure) and letter of credit fees payable under Section 3.05(b) with respect to such Defaulting Lender’s LC Exposure shall be payable to the Issuing Bank until such LC Exposure is reallocated and/or cash collateralized or otherwise backstopped; and

(iv)    So long as such Lender is a Defaulting Lender, the Issuing Bank shall not be required to issue, amend or increase any Letter of Credit, unless it is satisfied that the related exposure and the Defaulting Lender’s then outstanding LC Exposure will be 100% covered by the Commitments of the Non-Defaulting Lenders and/or cash collateral or other backstop arrangement will be provided by the Borrower in accordance with Section 4.03(c), and participating interests in any such newly issued or increased Letter of Credit shall be allocated among Non-Defaulting Lenders in a manner consistent with Section 4.03(c)(iii)(A) (and such Defaulting Lender shall not participate therein).

If a Bankruptcy Event or a Bail-In Action with respect to a Lender Parent of any Lender shall occur following the Effective Date and for so long as such event shall continue, the Issuing Bank shall not be required to issue, amend or increase any Letter of Credit, unless the Issuing Bank shall have entered into arrangements with the Borrower or such Lender, satisfactory to the Issuing Bank, as the case may be, to defease any risk to it in respect of such Lender hereunder.

In the event that the Administrative Agent, the Borrower and the Issuing Bank each agrees that a Defaulting Lender has adequately remedied all matters that caused such Lender to be a Defaulting Lender and such Lender is no longer a Defaulting Lender, then the LC Exposure of the Lenders shall be readjusted to reflect the inclusion of such Lender’s Commitment and on such date, if necessary, such Lender shall purchase at par such of the Loans and/or participations in

 

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Letters of Credit of the other Lenders as the Administrative Agent shall determine may be necessary in order for such Lender to hold such Loans and/or participations in Letters of Credit in accordance with its Applicable Percentage.

Section 4.04    Disposition of Proceeds. The Security Instruments contain an assignment by the Borrower and/or the Guarantors unto and in favor of the Administrative Agent for the benefit of the Secured Parties of all of the Borrower’s and/or each Guarantor’s interest in and to production and all proceeds attributable thereto which may be produced from or allocated to the Mortgaged Property. The Security Instruments further provide in general for the application of such proceeds to the satisfaction of the Obligations and other obligations described therein and secured thereby. Notwithstanding the assignment contained in such Security Instruments, for so long as no Event of Default has occurred and is continuing, (a) the Administrative Agent and the Secured Parties agree that they will neither notify the purchaser or purchasers of such production nor take any other action to cause such proceeds to be remitted to the Administrative Agent or the Secured Parties, but the Secured Parties will instead permit such proceeds to be paid to the Loan Parties and (b) the Secured Parties hereby authorize the Administrative Agent to take such actions as may be necessary to cause such proceeds to be paid to and retained by the Loan Parties.

ARTICLE V

INCREASED COSTS; BREAK FUNDING PAYMENTS; TAXES; ILLEGALITY

Section 5.01    Increased Costs.

(a)    Changes in Law. If any Change in Law shall:

(i)    impose, modify or deem applicable any reserve, special deposit, liquidity or similar requirement (including any compulsory loan requirement, insurance charge or other assessment) against assets of, deposits with or for the account of, or credit extended by, any Lender or the Issuing Bank;

(ii)    impose on any Lender or the Issuing Bank any other condition, cost or expense (other than Taxes) affecting this Agreement or Loans made by such Lender or any Letter of Credit or participation therein; or

(iii)    subject any Recipient under this Agreement or under any other Loan Document to any Taxes (other than (A) Indemnified Taxes, (B) Taxes described in clauses (b) through (d) of the definition of Excluded Taxes and (C) Connection Income Taxes) on its loans, loan principal, letters of credit, commitments, or other obligations, or its deposits, reserves, other liabilities or capital attributable thereto;

(iv)    and the result of any of the foregoing shall be to increase the cost to such Lender or such other Recipient of making, continuing, converting or maintaining any Loan (or of maintaining its obligation to make any such Loan) or to increase the cost to such Lender, the Issuing Bank or such other Recipient of participating in, issuing or maintaining any Letter of Credit or to reduce the amount of any sum received or receivable by such Lender, the Issuing Bank or such other Recipient hereunder (whether of principal, interest or otherwise), then the Borrower will pay to such Lender, the Issuing Bank or such other Recipient, as the case may be, such additional amount or amounts as will compensate such Lender, the Issuing Bank or such other Recipient, as the case may be, for such additional costs incurred or reduction suffered.

 

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(b)    Capital Requirements. If any Lender or the Issuing Bank determines that any Change in Law regarding capital or liquidity requirements has or would have the effect of reducing the rate of return on such Lender’s or the Issuing Bank’s capital or on the capital of such Lender’s or the Issuing Bank’s holding company, if any, as a consequence of this Agreement or the Loans made by, or participations in Letters of Credit held by, such Lender, or the Letters of Credit issued by the Issuing Bank, to a level below that which such Lender or the Issuing Bank or such Lender’s or the Issuing Bank’s holding company could have achieved but for such Change in Law (taking into consideration such Lender’s or the Issuing Bank’s policies and the policies of such Lender’s or the Issuing Bank’s holding company with respect to capital adequacy and liquidity), then from time to time the Borrower will pay to such Lender or the Issuing Bank, as the case may be, such additional amount or amounts as will compensate such Lender or the Issuing Bank or such Lender’s or the Issuing Bank’s holding company for any such reduction suffered.

(c)    Certificates. A certificate of a Lender, the Issuing Bank or other Recipient setting forth the amount or amounts necessary to compensate such Lender, the Issuing Bank or other Recipient or its holding company, as the case may be, as specified in Section 5.01(a) or (b) shall be delivered to the Borrower and shall be conclusive absent manifest error. The Borrower shall pay such Lender or the Issuing Bank, as the case may be, the amount shown as due on any such certificate within 10 days after receipt thereof.

(d)    Effect of Failure or Delay in Requesting Compensation. Failure or delay on the part of any Lender or the Issuing Bank to demand compensation pursuant to this Section 5.01 shall not constitute a waiver of such Lender’s or the Issuing Bank’s right to demand such compensation; provided that the Borrower shall not be required to compensate a Lender or the Issuing Bank pursuant to this Section 5.01 for any increased costs or reductions incurred more than 180 days prior to the date that such Lender or the Issuing Bank, as the case may be, notifies the Borrower of the Change in Law giving rise to such increased costs or reductions and of such Lender’s or the Issuing Bank’s intention to claim compensation therefor; provided, further that, if the Change in Law giving rise to such increased costs or reductions is retroactive, then the 180-day period referred to above shall be extended to include the period of retroactive effect thereof.

Section 5.02    Break Funding Payments. In the event of (a) the payment of any principal of any Term SOFR Loan other than on the last day of the Interest Period applicable thereto (including as a result of an Event of Default) (other than a payment required pursuant to Section 3.04(c)(vi)), (b) the conversion of any Term SOFR Loan other than on the last day of the Interest Period applicable thereto (including as a result of an Event of Default), (c) the failure to borrow, convert, continue or prepay any Term SOFR Loan on the date specified in any notice delivered pursuant hereto, or (d) the assignment of any Term SOFR Loan other than on the last day of the Interest Period applicable thereto as a result of a request by the Borrower pursuant to Section 5.04, then, in any such event, the Borrower shall compensate each Lender for any loss, cost and expense incurred by it as a result of such event, including any loss of anticipated profits and any loss or expense arising from the liquidation or reemployment of funds obtained by it to maintain such Loan or from fees payable to terminate the deposits from which such funds were obtained. The Borrower shall also pay any customary administrative fees charged by such Lender in connection with the foregoing.

 

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A certificate of any Lender setting forth any amount or amounts that such Lender is entitled to receive pursuant to this Section 5.02 shall be delivered to the Borrower and shall be conclusive absent manifest error. The Borrower shall pay such Lender the amount shown as due on any such certificate within 10 days after receipt thereof.

Section 5.03    Taxes.

(a)    Payments Free of Taxes. Any and all payments by or on account of any obligation of the Borrower or any Guarantor under any Loan Document shall be made without deduction or withholding for any Taxes, except as required by applicable law. If any applicable law (as determined in the good faith discretion of an applicable withholding agent) requires the deduction or withholding of any Tax from any such payment by a withholding agent, then the applicable withholding agent shall be entitled to make such deduction or withholding and shall timely pay the full amount deducted or withheld to the relevant Governmental Authority in accordance with applicable law and, if such Tax is an Indemnified Tax, then the sum payable by the Borrower or such Guarantor shall be increased as necessary so that after such deduction or withholding has been made (including such deductions and withholdings applicable to additional sums payable under this Section 5.03) the applicable Recipient receives an amount equal to the sum it would have received had no such deduction or withholding been made.

(b)    Payment of Other Taxes by the Borrower. The Borrower and each Guarantor shall timely pay to the relevant Governmental Authority in accordance with applicable law, or at the option of the Administrative Agent timely reimburse it for the payment of, Other Taxes.

(c)    Indemnification by the Borrower. The Borrower and each Guarantor shall jointly and severally indemnify each Recipient, within 10 days after written demand therefor, for the full amount of any Indemnified Taxes (including Indemnified Taxes imposed or asserted on or attributable to amounts payable under this Section) payable or paid by such Recipient or required to be withheld or deducted from a payment to such Recipient and any penalties, interest and reasonable out-of-pocket expenses arising therefrom or with respect thereto, whether or not such Indemnified Taxes were correctly or legally imposed or asserted by the relevant Governmental Authority. A certificate as to the amount of such payment or liability delivered to the Borrower by a Lender (with a copy to the Administrative Agent), or by the Administrative Agent on its own behalf or on behalf of a Lender, shall be conclusive absent manifest error.

(d)    Evidence of Payments. As soon as practicable after any payment of Taxes by the Borrower or any Guarantor to a Governmental Authority pursuant to this Section 5.03, the Borrower or such Guarantor shall deliver to the Administrative Agent the original or a certified copy of a receipt issued by such Governmental Authority evidencing such payment, a copy of the return reporting such payment or other evidence of such payment reasonably satisfactory to the Administrative Agent.

 

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(e)    Status of Lenders.

(i)    Any Lender that is entitled to an exemption from or reduction of withholding Tax with respect to payments made under any Loan Document shall deliver to the Borrower and the Administrative Agent, at the time or times reasonably requested by the Borrower or the Administrative Agent, such properly completed and executed documentation reasonably requested by the Borrower or the Administrative Agent as will permit such payments to be made without withholding or at a reduced rate of withholding. In addition, any Lender, if reasonably requested by the Borrower or the Administrative Agent, shall deliver such other documentation prescribed by applicable law or reasonably requested by the Borrower or the Administrative Agent as will enable the Borrower or the Administrative Agent to determine whether or not such Lender is subject to backup withholding or information reporting requirements. Notwithstanding anything to the contrary in the preceding two sentences, the completion, execution and submission of such documentation (other than such documentation set forth in Section 5.03(e)(ii)(A), Section 5.03(e)(ii)(B) and Section 5.03(e)(ii)(D) below) shall not be required if in the Lender’s reasonable judgment such completion, execution or submission would subject such Lender to any material unreimbursed cost or expense or would materially prejudice the legal or commercial position of such Lender.

(ii)    Without limiting the generality of the foregoing:

(A)    any Lender that is a U.S. Person shall deliver to the Borrower and the Administrative Agent on or prior to the date on which such Lender becomes a Lender under this Agreement (and from time to time thereafter upon the reasonable request of the Borrower or the Administrative Agent), executed copies of IRS Form W-9 (or any successor form) certifying that such Lender is exempt from U.S. federal backup withholding Tax;

(B)    any Foreign Lender shall, to the extent it is legally entitled to do so, deliver to the Borrower and the Administrative Agent (in such number of copies as shall be requested by the recipient) on or prior to the date on which such Foreign Lender becomes a Lender under this Agreement (and from time to time thereafter upon the reasonable request of the Borrower or the Administrative Agent), whichever of the following is applicable:

(1)    in the case of a Foreign Lender claiming the benefits of an income Tax treaty to which the United States is a party (x) with respect to payments of interest under any Loan Document, executed copies of IRS Form W-8BEN or IRS Form W-8BEN-E (or any successor form) establishing an exemption from, or reduction of, U.S. federal withholding Tax pursuant to the “interest” article of such tax treaty and (y) with respect to any other applicable payments under any Loan Document, IRS Form W-8BEN or IRS Form W-8BEN-E establishing an exemption from, or reduction of, U.S. federal withholding Tax pursuant to the “business profits” or “other income” article of such tax treaty;

(2)    in the case of a Foreign Lender claiming that its extension of credit will generate U.S. effectively connected income, executed copies of IRS Form W-8ECI (or any successor form);

(3)    in the case of a Foreign Lender claiming the benefits of the exemption for portfolio interest under Section 881(c) of the Code, (x) a certificate substantially in the form of Exhibit H-1 to the effect that such Foreign Lender is not a “bank”

 

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within the meaning of Section 881(c)(3)(A) of the Code, a “10 percent shareholder” of the Borrower within the meaning of Section 881(c)(3)(B) of the Code, or a “controlled foreign corporation” described in Section 881(c)(3)(C) of the Code (a “U.S. Tax Compliance Certificate”) and (y) executed copies of IRS Form W-8BEN or IRS Form W-8BEN-E (or any successor form); or

(4)    to the extent a Foreign Lender is not the beneficial owner, executed copies of IRS Form W-8IMY (or any successor form), accompanied by IRS Form W-8ECI (or any successor form), IRS Form W-8BEN or IRS Form W-8BEN-E (or any successor form), a U.S. Tax Compliance Certificate substantially in the form of Exhibit H-2 or Exhibit H-3, IRS Form W-9 (or any successor form), and/or other certification documents from each beneficial owner, as applicable; provided that if the Foreign Lender is a partnership and one or more direct or indirect partners of such Foreign Lender are claiming the portfolio interest exemption, such Foreign Lender may provide a U.S. Tax Compliance Certificate substantially in the form of Exhibit H-4 on behalf of each such direct and indirect partner;

(C)    any Foreign Lender shall, to the extent it is legally entitled to do so, deliver to the Borrower and the Administrative Agent (in such number of copies as shall be requested by the recipient) on or prior to the date on which such Foreign Lender becomes a Lender under this Agreement (and from time to time thereafter upon the reasonable request of the Borrower or the Administrative Agent), executed copies of any other form prescribed by applicable law as a basis for claiming exemption from or a reduction in U.S. federal withholding Tax, duly completed, together with such supplementary documentation as may be prescribed by applicable law to permit the Borrower or the Administrative Agent to determine the withholding or deduction required to be made; and

(D)    if a payment made to a Recipient under any Loan Document would be subject to U.S. federal withholding Tax imposed by FATCA if such Recipient were to fail to comply with the applicable reporting requirements of FATCA (including those contained in Section 1471(b) or 1472(b) of the Code, as applicable), such Lender shall deliver to the Borrower and the Administrative Agent at the time or times prescribed by law and at such time or times reasonably requested by the Borrower or the Administrative Agent such documentation prescribed by applicable law (including as prescribed by Section 1471(b)(3)(C)(i) of the Code) and such additional documentation reasonably requested by the Borrower or the Administrative Agent as may be necessary for the Borrower and the Administrative Agent to comply with their obligations under FATCA and to determine that such Recipient has complied with such Recipient’s obligations under FATCA or to determine the amount to deduct and withhold from such payment. Solely for purposes of this clause (D), “FATCA” shall include any amendments made to FATCA after the date of this Agreement.

Each Lender agrees that if any form or certification it previously delivered expires or becomes obsolete or inaccurate in any respect, it shall update such form or certification or promptly notify the Borrower and the Administrative Agent in writing of its legal inability to do so.

(f)    Indemnification by the Lenders. Each Lender shall severally indemnify the Administrative Agent, within 10 days after demand therefor, for (i) any Indemnified Taxes attributable to such Lender (but only to the extent that the Borrower or any Guarantor has not

 

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already indemnified the Administrative Agent for such Indemnified Taxes and without limiting the obligation of the Borrower and each Guarantor to do so), (ii) any Taxes attributable to such Lender’s failure to comply with the provisions of Section 12.04(c) relating to the maintenance of a Participant Register and (iii) any Excluded Taxes attributable to such Lender, in each case, that are payable or paid by the Administrative Agent in connection with any Loan Document, and any reasonable expenses arising therefrom or with respect thereto, whether or not such Taxes were correctly or legally imposed or asserted by the relevant Governmental Authority. A certificate as to the amount of such payment or liability delivered to any Lender by the Administrative Agent shall be conclusive absent manifest error. Each Lender hereby authorizes the Administrative Agent to set off and apply any and all amounts at any time owing to such Lender under any Loan Document or otherwise payable by the Administrative Agent to the Lender from any other source against any amount due to the Administrative Agent under this paragraph (f).

(g)    Treatment of Certain Refunds. If any party determines, in its sole discretion exercised in good faith, that it has received a refund of any Taxes as to which it has been indemnified pursuant to this Section 5.03 (including by the payment of additional amounts pursuant to this Section 5.03), it shall pay to the indemnifying party an amount equal to such refund (but only to the extent of indemnity payments made under this Section 5.03 with respect to the Taxes giving rise to such refund), net of all out-of-pocket expenses (including Taxes) of such indemnified party and without interest (other than any interest paid by the relevant Governmental Authority with respect to such refund). Such indemnifying party, upon the request of such indemnified party, shall repay to such indemnified party the amount paid over pursuant to this paragraph (g) (plus any penalties, interest or other charges imposed by the relevant Governmental Authority) in the event that such indemnified party is required to repay such refund to such Governmental Authority. Notwithstanding anything to the contrary in this paragraph (g), in no event will the indemnified party be required to pay any amount to an indemnifying party pursuant to this paragraph (g) the payment of which would place the indemnified party in a less favorable net after-Tax position than the indemnified party would have been in if the Tax subject to indemnification and giving rise to such refund had not been deducted, withheld or otherwise imposed and the indemnification payments or additional amounts with respect to such Tax had never been paid. This paragraph shall not be construed to require any indemnified party to make available its Tax returns (or any other information relating to its Taxes that it deems confidential) to the indemnifying party or any other Person.

(h)    Survival. Each party’s obligations under this Section 5.03 shall survive the resignation or replacement of the Administrative Agent or any assignment of rights by, or the replacement of, a Lender, the termination of the Commitments and the repayment, satisfaction or discharge of all obligations under any Loan Document.

(i)    Defined Terms. For purposes of this Section 5.03, the term “Lender” includes the Issuing Bank and the term “applicable law” includes FATCA.

Section 5.04    Mitigation Obligations; Replacement of Lenders.

(a)    Mitigation Obligations. If any Lender requests compensation under Section 5.01, or if the Borrower is required to pay any Indemnified Taxes or additional amounts to any Lender or any Governmental Authority for the account of any Lender pursuant to

 

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Section 5.03, then such Lender shall use reasonable efforts to designate a different lending office for funding or booking its Loans hereunder or to assign its rights and obligations hereunder to another of its offices, branches or affiliates, if, in the judgment of such Lender, such designation or assignment (i) would eliminate or reduce amounts payable pursuant to Section 5.01 or Section 5.03, as the case may be, in the future and (ii) would not subject such Lender to any unreimbursed cost or expense and would not otherwise be disadvantageous to such Lender. The Borrower hereby agrees to pay all reasonable costs and expenses incurred by any Lender in connection with any such designation or assignment.

(b)    Replacement of Lenders. If (i) any Lender requests compensation under Section 5.01, (ii) the Borrower or any Guarantor is required to pay any Indemnified Taxes or additional amounts to any Lender or any Governmental Authority for the account of any Lender or indemnify any Lender pursuant to Section 5.03, (iii) any Lender becomes a Defaulting Lender, or (iv) any Lender becomes a Non-Consenting Lender, then the Borrower may, at its sole expense and effort, upon notice to such Lender and the Administrative Agent, require such Lender to assign and delegate, without recourse (in accordance with and subject to the restrictions contained in Section 12.04(b)), all its interests, rights (other than its existing rights to payments pursuant to Section 5.01 or Section 5.03) and obligations under this Agreement and the other Loan Documents to an assignee that shall assume such obligations (which assignee may be another Lender, if a Lender accepts such assignment); provided that (A) the Administrative Agent shall have received the assignment fee (if any) specified in Section 12.04 (or waived such assignment fee), (B) such Lender shall have received payment of an amount equal to the outstanding principal of its Loans and participations in LC Disbursements, accrued interest thereon, accrued fees and all other amounts payable to it hereunder, from the assignee (to the extent of such outstanding principal and accrued interest and fees) or the Borrower (in the case of all other amounts), (C) in the case of any such assignment resulting from a claim for compensation under Section 5.01 or payments required to be made pursuant to Section 5.03, such assignment will result in a reduction in such compensation or payments (D) such assignment does not conflict with applicable laws and (E) in the case of any assignment resulting from a Lender becoming a Non-Consenting Lender, the applicable assignee shall have consented to the applicable amendment, waiver or consent. A Lender shall not be required to make any such assignment and delegation if, prior thereto, as a result of a waiver by such Lender or otherwise, the circumstances entitling the Borrower to require such assignment and delegation cease to apply. Notwithstanding the foregoing, a Lender shall not be required to make any such assignment and delegation if such Lender or any of its Affiliates is a Secured Swap Party with any outstanding Secured Swap Agreement, unless on or prior thereto, all such Swap Agreements have been terminated or novated to another Person and such Lender (or its Affiliate) shall have received payment of all amounts, if any, payable to it in connection with such termination or novation. Each party hereto agrees that (i) an assignment required pursuant to this Section 5.04(b) may be effected pursuant to an Assignment and Assumption executed by the Borrower, the Administrative Agent and the assignee (or, to the extent applicable, an agreement incorporating an Assignment and Assumption by reference pursuant to an Approved Electronic Platform as to which the Administrative Agent and such parties are participants), and (ii) the Lender required to make such assignment need not be a party thereto in order for such assignment to be effective and shall be deemed to have consented to an be bound by the terms thereof; provided that, following the effectiveness of any such assignment, the other parties to such assignment agree to execute and deliver such documents necessary to evidence such assignment as reasonably requested by the applicable Lender; provided that any such documents shall be without recourse to or warranty by the parties thereto.

 

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(c)    Notwithstanding anything in this Section 5.04 to the contrary, (i) the Lender that acts as the Issuing Bank may not be replaced hereunder at any time it has any Letter of Credit outstanding hereunder unless arrangements satisfactory to such Lender (including the furnishing of a backstop standby letter of credit in form and substance, and issued by an issuer, reasonably satisfactory to the Issuing Bank or the depositing of cash collateral into a cash collateral account in amounts and pursuant to arrangements reasonably satisfactory to the Issuing Bank) have been made with respect to such outstanding Letter of Credit and (ii) a Lender that acts as the Administrative Agent may not be replaced hereunder except in accordance with the terms of Section 11.06.

Section 5.05    Illegality. If any Lender determines that any Governmental Requirement has made it unlawful, or that any Governmental Authority has asserted that it is unlawful, for any Lender or its applicable lending office to make, maintain or fund Loans whose interest is determined by reference to the SOFR or Term SOFR, or to determine or charge interest rates based upon the SOFR or Term SOFR, then, upon notice thereof by such Lender to the Borrower (through the Administrative Agent), (a) any obligation of the Lenders to make or continue Term SOFR Loans or to convert ABR Loans to SOFR Loans, shall be suspended and (b) ) if such notice asserts the illegality of such Lender making or maintaining ABR Loans the interest rate on which is determined by reference to the Term SOFR component of the Alternate Base Rate, if necessary to avoid such illegality, the interest rate applicable to ABR Loans shall be determined by the Administrative Agent without reference to clause (c) of the definition of “Alternate Base Rate”, in each case until such Lender notifies the Administrative Agent and the Borrower that the circumstances giving rise to such determination no longer exist. Upon receipt of such notice, (i) the Borrower shall, if necessary to avoid such illegality, upon demand from any Lender (with a copy to the Administrative Agent), prepay or, if applicable, convert all Term SOFR Loans to ABR Loans (the interest rate applicable to the ABR Loans of such Lender shall, if necessary to avoid such illegality, be determined by the Administrative Agent without reference to clause (c) of the definition of “Alternate Base Rate”), on the last day of the Interest Period thereof, if all affected Lenders may lawfully continue to maintain such Term SOFR Loans to such day, or immediately, if any Lender may not lawfully continue to maintain such Term SOFR Loans to such day, and (ii) if necessary to avoid such illegality, the Administrative Agent shall during the period of such suspension compute the Alternate Base Rate without reference to clause (c) of the definition thereof, in each case, until the Administrative Agent is advised in writing by each affected Lender that it is no longer illegal for such Lender to determine or charge interest rates based upon the SOFR. Upon any such prepayment or conversion, the Borrower shall also pay accrued interest on the amount so prepaid or converted, together with any additional amounts required pursuant to Section 5.02.

 

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ARTICLE VI

CONDITIONS PRECEDENT

Section 6.01    Effective Date. The obligations of the Lenders to make Loans and of the Issuing Bank to issue Letters of Credit hereunder shall not become effective until the date on which each of the following conditions is satisfied (or waived in accordance with Section 12.02):

(a)    The Administrative Agent, the Arranger and the Lenders shall have received or shall, substantially concurrently with the Effective Date, receive all commitment, arrangement, upfront and agency fees and all other fees and amounts due and payable on or prior to the Effective Date, including pursuant to the Fee Letters, and to the extent invoiced at least one (1) Business Day prior to the Effective Date, reimbursement or payment of all reasonable and documented out-of-pocket expenses required to be reimbursed or paid by the Borrower hereunder.

(b)    The Administrative Agent shall have received a certificate of a Responsible Officer of the GP Pledgor, the Borrower and each Guarantor setting forth (i) resolutions of the members, board of directors, board of managers or other appropriate governing body with respect to the authorization of the GP Pledgor, the Borrower or such Guarantor to execute and deliver the Loan Documents to which it is a party and to enter into the transactions contemplated in those documents, (ii) the officers of the GP Pledgor, the Borrower or such Guarantor, or of the manager, managing member, general partner or such other Person having authority to bind the GP Pledgor, the Borrower or such Guarantor, (A) who are authorized to sign the Loan Documents to which the GP Pledgor, the Borrower or such Guarantor is a party and (B) who will, until replaced by another officer or officers duly authorized for that purpose, act as its representative for the purposes of signing documents and giving notices and other communications in connection with this Agreement and the transactions contemplated hereby, (iii) specimen signatures of such authorized officers, and (iv) the articles or certificate of incorporation, by-laws, the limited liability company agreement, operating agreement, partnership agreement, certificate of formation or other applicable organizational documents of the GP Pledgor, the Borrower and such Guarantor (in each case, together with all amendments thereto, if any), certified as being true and complete. The Administrative Agent and the Lenders may conclusively rely on items covered in clauses (ii) and (iii) of such certificate until the Administrative Agent receives notice in writing from the Borrower to the contrary.

(c)    The Administrative Agent shall have received a certificate from the jurisdiction of formation with respect to the existence, qualification and good standing of the GP Pledgor, the Borrower and each Guarantor.

(d)    The Administrative Agent shall have received from each party hereto counterparts (in such number as may be requested by the Administrative Agent) of this Agreement signed on behalf of such party.

(e)    The Administrative Agent shall have received duly executed Notes payable to each Lender that has, prior to the Effective Date, requested a Note in a principal amount equal to its Maximum Credit Amount dated as of the Effective Date.

(f)    The Administrative Agent shall have received from each party thereto duly executed counterparts (in such number as may be requested by the Administrative Agent) of the Security Instruments required to be executed on the Effective Date, which are described on Exhibit E. In connection with the execution and delivery of the Security Instruments, the Administrative Agent shall be reasonably satisfied that the Security Instruments create first priority (and upon filing in the proper offices of the appropriate jurisdictions, perfected) Liens (provided that Excepted Liens identified in clauses (a), (b), (c), (d), (f) and (m) of the definition thereof may exist, but subject to the provisos at the end of such definition) on at least 85% of the total value of the proved Oil and Gas Properties evaluated in the Initial Reserve Report.

 

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(g)    The Administrative Agent shall have received a customary opinion of Latham & Watkins LLP, special counsel to the Borrower, in form and substance reasonably satisfactory to the Administrative Agent.

(h)    Subject to Section 8.19, the Administrative Agent shall have received a certificate of insurance coverage of the Borrower evidencing that the Loan Parties are carrying insurance in accordance with Section 7.12.

(i)    The Administrative Agent shall have received (i) title information reasonably satisfactory to the Administrative agent setting forth the status of title to at least 85% of the total value of the proved Oil and Gas Properties evaluated in the Initial Reserve Report and (ii) the Initial Reserve Report accompanied by a certificate covering the matters described in Section 8.12(c).

(j)    The Administrative Agent shall have received a certificate from a Financial Officer of the Borrower with respect to the solvency of the Loan Parties on a consolidated basis as of the Effective Date after giving effect to the Transactions, in form and substance reasonably satisfactory to the Administrative Agent.

(k)    The Administrative Agent shall have received a certificate of a Responsible Officer of the Borrower certifying (i) that the Loan Parties have received all consents and approvals required by Section 7.03 and (ii) as to the matters set forth in Section 6.01(p), Section 6.02(a) and Section 6.02(b).

(l)    The Administrative Agent shall have received (i) the Financial Statements referred to in Section 7.04(a) and (ii) the pro forma cash flow model referred to in Section 7.04(b), with such cash flow model certified by a Responsible Officer of the Borrower as having been prepared in good faith based upon reasonable assumptions at the time of preparation.

(m)    On the Effective Date, after giving effect to the Transactions (including, for the avoidance of doubt, the Effective Date Refinancing), none of the Loan Parties shall have any outstanding Debt for borrowed money other than Debt permitted pursuant to Section 9.02. The Administrative Agent shall have received appropriate UCC search certificates reflecting no prior Liens encumbering the Properties of the Loan Parties (other than those being assigned or released on or prior to the Effective Date or Liens permitted by Section 9.03) for Delaware and any other jurisdiction reasonably requested by the Administrative Agent, other than those Liens being assigned or released on or prior to the Effective Date or Liens permitted by Section 9.03. The Administrative Agent shall have received evidence reasonably satisfactory to it that all Liens on the Property of the Loan Parties (other than Liens permitted by Section 9.03) have been (or will be concurrently with the initial Borrowing on the Effective Date) released or terminated, and that duly executed recordable releases and terminations in forms reasonably acceptable to the Administrative Agent with respect thereto have been obtained by the Loan Parties.

 

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(n)    The Administrative Agent shall be satisfied that on the Effective Date, after giving effect to the Transactions contemplated to occur on the Effective Date, the unused Commitments shall be greater than or equal to 20% of the total Commitments.

(o)    The Administrative Agent shall be satisfied with the environmental condition of the Loan Parties’ Properties.

(p)    The Merger shall have been (or contemporaneously with the Effective Date shall be) consummated in accordance with the terms of the Merger Agreement and the Administrative Agent shall have received a true and complete executed copy of the Merger Agreement.

(q)    The Administrative Agent and the Lenders shall have received, at least 3 Business Days prior to the date of this Agreement to the extent requested at least 5 Business Days prior to the date of this Agreement, (i) all documentation and other information required by bank regulatory authorities under applicable “know-your-customer” and anti-money laundering rules and regulations, including but not restricted to the USA PATRIOT Act and (ii) a Beneficial Ownership Certification in relation to the Borrower or any Guarantor that qualifies as a “legal entity customer” under the Beneficial Ownership Regulation.

The Administrative Agent shall notify the Borrower and the Lenders of the Effective Date, and such notice shall be conclusive and binding. Notwithstanding the foregoing, the obligations of the Lenders to make Loans and of the Issuing Bank to issue Letters of Credit hereunder shall not become effective unless each of the foregoing conditions is satisfied (or waived pursuant to Section 12.02) at or prior to 5:00 p.m., Houston, Texas time, on June 7, 2022 (and, in the event such conditions are not so satisfied, extended or waived, the Commitments shall terminate at such time). For purposes of determining compliance with the conditions specified in this Section 6.01, each Lender that has signed this Agreement shall be deemed to have consented to, approved or accepted or to be satisfied with, each document or other matter required thereunder to be consented to or approved by or acceptable or satisfactory to a Lender unless the Administrative Agent shall have received written notice from such Lender prior to the proposed Effective Date specifying its objection thereto.

Section 6.02    Each Credit Event. The obligation of each Lender to make a Loan on the occasion of any Borrowing (including the initial funding but excluding any conversion or continuation of Loans pursuant to Section 2.04), and of the Issuing Bank to issue, amend, renew or extend any Letter of Credit, is subject to the satisfaction of the following conditions:

(a)    At the time of and immediately after giving effect to such Borrowing or the issuance, amendment, renewal or extension of such Letter of Credit, as applicable, no Default shall have occurred and be continuing.

(b)    The representations and warranties of the Borrower and the Guarantors set forth in this Agreement and in the other Loan Documents shall be true and correct in all material respects (except to the extent any such representations and warranties are limited by materiality, in which case, they shall be true and correct in all respects) on and as of the date of such Borrowing or the date of issuance, amendment, renewal or extension of such Letter of Credit, as applicable,

 

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except to the extent any such representations and warranties are expressly limited to an earlier date, in which case, on and as of the date of such Borrowing or the date of issuance, amendment, renewal or extension of such Letter of Credit, as applicable, such representations and warranties shall continue to be true and correct in all material respects (except to the extent any such representations and warranties are limited by materiality, in which case, they shall be true and correct in all respects) as of such specified earlier date.

(c)    The receipt by the Administrative Agent of a Borrowing Request in accordance with Section 2.03 or a request for a Letter of Credit in accordance with Section 2.08(b), as applicable.

(d)    At the time of and immediately after giving effect to such Borrowing or the issuance, amendment, renewal or extension of such Letter of Credit, as applicable, no Excess Cash exists.

Each request for a Borrowing (other than a conversion or continuation of Loans) and each request for the issuance, amendment, renewal or extension of any Letter of Credit shall be deemed to constitute a representation and warranty by the Borrower on the date thereof as to the matters specified in Section 6.02(a), (b), and (d).

ARTICLE VII

REPRESENTATIONS AND WARRANTIES

The Borrower represents and warrants to the Lenders, on the date of each Credit Event and on any other date upon which such representations and warranties are expressly made pursuant to any Loan Document, that:

Section 7.01    Organization; Powers. Each of the Loan Parties is duly organized, validly existing and in good standing under the laws of the jurisdiction of its organization, has all requisite power and authority, and has all material governmental licenses, authorizations, consents and approvals necessary, to own its assets and to carry on its business as now conducted, and is qualified to do business in, and is in good standing in, every jurisdiction where such qualification is required, except where failure to have such power, authority, licenses, authorizations, consents, approvals and qualifications could not reasonably be expected to have a Material Adverse Effect.

Section 7.02    Authority; Enforceability. The Transactions and each Borrowing or the issuance, amendment, renewal or extension of a Letter of Credit, as applicable, are within the Borrower’s and each Guarantor’s corporate or equivalent powers and have been duly authorized by all necessary corporate or equivalent action (including, without limitation, any action required to be taken by any other Person, whether interested or disinterested, in order to ensure the due authorization of the Transactions. Each Loan Document to which the Borrower and each Guarantor is a party has been duly executed and delivered by the Borrower and such Guarantor, as applicable, and constitutes a legal, valid and binding obligation of the Borrower and such Guarantor, as applicable, enforceable in accordance with its terms, subject to applicable bankruptcy, insolvency, reorganization, moratorium or other laws affecting creditors’ rights generally and subject to general principles of equity, regardless of whether considered in a proceeding in equity or at law.

 

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Section 7.03    Approvals; No Conflicts. The Transactions (a) do not require any consent or approval of, registration or filing with, or any other action by, any Governmental Authority or any other third Person (including holders of its Equity Interests or any class of directors, managers or supervisors, as applicable, whether interested or disinterested, of the Borrower or any other Person), nor is any such consent, approval, registration, filing or other action necessary for the validity or enforceability of any Loan Document or the consummation of the Transactions, except such as have been obtained or made and are in full force and effect other than (i) the recording and filing of the Security Instruments as required by this Agreement (together with and any financing statements or other filings or recordings required under the Loan Documents) and (ii) those third party approvals or consents which, if not made or obtained would not cause a Default hereunder, could not reasonably be expected to have a Material Adverse Effect or do not have an adverse effect on the enforceability of the Loan Documents, (b) will not violate in any material respect any applicable law or regulation, or violate the charter, bylaws or other organizational documents of the Loan Parties or any order of any Governmental Authority, and (c) will not violate or result in a default under any indenture, agreement or other instrument evidencing Material Debt binding upon the Loan Parties or any of their respective Properties, or give rise to a right thereunder to require any payment to be made by the Loan Parties and will not result in the creation or imposition of any Lien on any Property of the Loan Parties (other than, in each case, the Liens created by the Loan Documents).

Section 7.04    Financial Condition; No Material Adverse Change.

(a)    Reference is made to the Parent’s audited consolidated balance sheets and statements of income, members’ equity and cash flows as of and for the fiscal year ending December 31, 2021 and filed with the SEC. Such financial statements of Parent present fairly, in all material respects, the financial position and results of operations and cash flows of the Parent and the New Loan Parties as of such date and for such period in accordance with GAAP.

(b)    The Borrower has heretofore furnished to the Lenders a reasonably satisfactory pro forma cash flow model and projections (including cash flow and outstanding Debt projections), of the Borrower and its Consolidated Restricted Subsidiaries as of the Effective Date, after giving effect to the Transactions contemplated to occur on the Effective Date, certified by a Responsible Officer as having been prepared in good faith based upon reasonable assumptions, it being understood that such projections, including any revenues and volumes attributable to the Oil and Gas Properties of the Loan Parties and production and cost estimates are necessarily based upon professional opinions, estimates and projections and that the Loan Parties do not warrant that such opinions, estimates and projections will ultimately prove to have been accurate.

(c)    Since December 31, 2021, there has been no event, development or circumstance that has had or could reasonably be expected to have a Material Adverse Effect.

(d)    No Loan Party has on the Effective Date and thereafter any Material Debt (including Disqualified Capital Stock) or any contingent liabilities, off-balance sheet liabilities or partnerships, liabilities for taxes, unusual forward or long-term commitments or unrealized or anticipated losses from any unfavorable commitments, except as referred to or reflected or provided for in the Financial Statements or otherwise disclosed in writing to the Administrative Agent.

 

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Section 7.05    Litigation. There are no actions, suits, investigations or proceedings by or before any arbitrator or Governmental Authority pending against or, to the knowledge of the Borrower, threatened in writing against the Loan Parties (i) not covered by insurance (except for normal deductibles and customary policy exclusions) that, if adversely determined, could reasonably be expected, individually or in the aggregate, to result in a Material Adverse Effect or (ii) that involve any Loan Document or, except as set forth on Schedule 7.05, the Transactions.

Section 7.06    Environmental Matters. Except for such matters that, individually or in the aggregate, could not reasonably be expected to have a Material Adverse Effect:

(a)    the Loan Parties and each of their respective Properties and operations thereon are, and to the Borrower’s knowledge, since December 31, 2021, have been in compliance with all applicable Environmental Laws;

(b)    the Loan Parties have obtained all Environmental Permits required for their respective operations and each of their Properties, with all such Environmental Permits being currently in full force and effect, and none of the Loan Parties has received any written notice or otherwise has knowledge that any such existing Environmental Permit will be revoked or that any application for any new Environmental Permit or renewal of any existing Environmental Permit will be protested or denied;

(c)    there are no claims, demands, suits, orders, inquiries, or proceedings concerning any violation of, or any liability (including as a potentially responsible party) under, any applicable Environmental Law that is pending or, to the Borrower’s knowledge, threatened in writing against the Loan Parties or any of their respective Properties;

(d)    [reserved];

(e)    except as permitted under applicable laws, there has been no Release or, to the Borrower’s knowledge, threatened Release, of Hazardous Materials at, on, under or from the Loan Parties’ Properties;

(f)    no Loan Party has received any written notice asserting an alleged liability or obligation under any applicable Environmental Laws with respect to the investigation, remediation, abatement, removal, or monitoring of any Hazardous Materials at, under, or Released or threatened to be Released from any real properties offsite the Loan Parties’ Properties and, to the Borrower’s knowledge, there are no conditions or circumstances that would reasonably be expected to result in the receipt of such written notice;

(g)    [reserved]; and

(h)    the Loan Parties have provided to the Lenders complete and correct copies of all environmental site assessment reports, investigations, studies, analyses, and correspondence on environmental matters (including matters relating to any alleged non-compliance with or liability under Environmental Laws) that are in the Loan Parties’ possession or control and relating to their respective Properties or operations thereon.

 

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Section 7.07    Compliance with the Laws and Agreements; No Defaults.

(a)    Each Loan Party is in compliance with all Governmental Requirements applicable to it or its Property and all agreements and other instruments binding upon it or its Property, and possesses all licenses, permits, franchises, exemptions, approvals and other governmental authorizations necessary for the ownership of its Property and the conduct of its business, except where the failure to do so, individually or in the aggregate, could not reasonably be expected to result in a Material Adverse Effect.

(b)    No Default has occurred and is continuing.

Section 7.08    Investment Company Act. No Loan Party is an “investment company” or a company “controlled” by an “investment company,” within the meaning of, or subject to regulation under, the Investment Company Act of 1940, as amended.

Section 7.09    Taxes. Each of the Loan Parties has timely filed or caused to be filed all income and other material Tax returns and reports required to have been filed and has paid or caused to be paid all Taxes required to have been paid by it, except (a) Taxes that are being contested in good faith by appropriate proceedings and for which a Loan Party has set aside on its books adequate reserves in accordance with GAAP and (b) to the extent that the failure to do so could not reasonably be expected to result in a Material Adverse Effect. The charges, accruals and reserves on the books of the Loan Parties and their Subsidiaries in respect of Taxes and other governmental charges are, in the reasonable opinion of the Borrower, adequate. No Tax Lien has been filed (other than Liens for Taxes not yet due and payable, or Liens for Taxes being contested in good faith by appropriate proceedings) and, to the knowledge of the Borrower, no claim is being asserted with respect to any such Tax or other such governmental charge.

Section 7.10    ERISA. No Loan Party sponsors, maintains, or contributes to, or has at any time in the six-year period preceding the Effective Date sponsored, maintained or contributed to, any Plan or Multiemployer Plan. Except as could not reasonably be expected to constitute a Material Adverse Effect, no ERISA Event has occurred.

Section 7.11    Disclosure; No Material Misstatements.

(a)    The Borrower has disclosed or made available to the Administrative Agent and the Lenders all agreements, instruments and corporate or other restrictions to which it, or any of the other Loan Parties is subject, and all other matters known to it, that, individually or in the aggregate, could reasonably be expected to result in a Material Adverse Effect. None of the other reports, financial statements, certificates or other information furnished by or on behalf of the Loan Parties to the Administrative Agent or any Lender or any of their Affiliates in connection with the negotiation of this Agreement or any other Loan Document or delivered hereunder or under any other Loan Document (as modified or supplemented by other information so furnished (including, with respect to the Information)), when taken as a whole, contains any material misstatement of fact or omits to state any material fact necessary to make the statements therein, in the light of the circumstances under which they were made, not misleading as of the date made or deemed made; provided that, with respect to projected financial information, the Borrower represents only that such information was prepared in good faith based upon assumptions believed to be reasonable at the time such financial information was prepared. To the knowledge of the Borrower, there are no statements or conclusions in any Reserve Report which are based upon or include materially

 

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misleading information or fail to take into account material information regarding the matters reported therein, it being understood that projections concerning volumes attributable to the Oil and Gas Properties of the Loan Parties and production and cost estimates contained in each Reserve Report are necessarily based upon professional opinions, estimates and projections and that the Loan Parties do not warrant that such opinions, estimates and projections will ultimately prove to have been accurate.

(b)    As of the Effective Date, the information included in the Beneficial Ownership Certification is true and correct in all respects.

Section 7.12    Insurance. The Borrower has, and has caused all of the other Loan Parties to have, (a) insurance policies sufficient for the compliance by each of them with all material Governmental Requirements and all applicable material agreements and (b) insurance coverage in at least amounts and against such risk (including, without limitation, public liability) that are usually insured against by companies similarly situated and engaged in the same or a similar business for the assets and operations of the Loan Parties. Subject to Section 8.19, such insurance policies contain an endorsement naming the Administrative Agent and the Lenders as additional insureds in respect of such liability insurance policies and naming the Administrative Agent as lender loss payee with respect to Property loss insurance.

Section 7.13    Restriction on Liens. No Loan Party is a party to any agreement or arrangement, or subject to any order, judgment, writ or decree, which either (i) restricts or purports to restrict its ability to grant Liens to the Administrative Agent and the Lenders on or in respect of their Properties to secure the Obligations and the Loan Documents, or (ii) restricts any Restricted Subsidiary from paying dividends or making any other distributions in respect of its Equity Interests to the Borrower or any Restricted Subsidiary, or (iii) restricts any Loan Party from making loans or advances or transferring any Property to the Borrower or any Restricted Subsidiary, or (iv) which requires the consent of or notice to other Persons in connection therewith; provided that the foregoing shall not apply to restrictions and conditions permitted under Section 9.16.

Section 7.14    Subsidiaries. Except as set forth on Schedule 7.14 or as disclosed in writing to the Administrative Agent (which shall promptly furnish a copy to the Lenders), which shall be a supplement to Schedule 7.14, (a) the Borrower has no Subsidiaries, (b) each Subsidiary is a Restricted Subsidiary, (c) each Restricted Subsidiary is a Material Subsidiary and (d) each Restricted Subsidiary is a Wholly-Owned Subsidiary. The Borrower has no Foreign Subsidiaries.

Section 7.15    Jurisdiction of Organization. As of the Effective Date, the Borrower’s jurisdiction of organization is Delaware and the name of the Borrower as listed in the public records of its jurisdiction of organization is Sitio Royalties Operating Partnership, LP.

Section 7.16    Properties; Titles, Etc.

(a)    Each of the Loan Parties has good and defensible title to their respective Oil and Gas Properties evaluated in the most recently delivered Reserve Report and good title to all its material personal Properties, in each case other than Properties sold, transferred, leased or otherwise Disposed of in compliance with Section 9.12 from time to time, free and clear of all Liens except Liens permitted by Section 9.03. After giving full effect to the Excepted Liens, the

 

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Loan Party specified as the owner owns the net interests in production attributable to the Hydrocarbon Interests as reflected in the most recently delivered Reserve Report, and the ownership of such Properties shall not in any material respect obligate the Loan Parties to bear the costs and expenses relating to the maintenance, development and operations of each such Property in an amount in excess of the working interest of each Property set forth in the most recently delivered Reserve Report that is not offset by a corresponding proportionate increase in the Loan Parties’ net revenue interest in such Property.

(b)    All material leases and agreements necessary for the conduct of the business of the Loan Parties are valid and subsisting, in full force and effect, and there exists no default or event or circumstance which with the giving of notice or the passage of time or both would give rise to a default under any such lease or leases, which could reasonably be expected to have a Material Adverse Effect.

(c)    The rights and Properties presently owned, leased or licensed by the Loan Parties including, without limitation, all easements and rights of way, include all rights and Properties necessary to permit the Loan Parties to conduct their business in all material respects in the same manner as its business has been conducted prior to the Effective Date.

(d)    All of the Properties of Loan Parties which are reasonably necessary for the operation of their businesses are in good working condition and are maintained in accordance with prudent industry standards, except to the extent any failure to satisfy the foregoing could not reasonably be expected to have a Material Adverse Effect.

(e)    Each of the Loan Parties owns, or is licensed to use, all trademarks, tradenames, copyrights, patents and other intellectual Property material to its business, and the use thereof by the Loan Parties does not infringe upon the rights of any other Person, except for any such infringements that, individually or in the aggregate, could not reasonably be expected to result in a Material Adverse Effect. The Loan Parties either own or have valid licenses or other rights to use all databases, geological data, geophysical data, engineering data, seismic data, maps, interpretations and other technical information used in their businesses as presently conducted, subject to the limitations contained in the agreements governing the use of the same, which limitations are customary for companies engaged in the oil and gas minerals business, with such exceptions as could not reasonably be expected to have a Material Adverse Effect.

Section 7.17    Maintenance of Properties. Except for such acts or failures to act as could not be reasonably expected to have a Material Adverse Effect, the Oil and Gas Properties with respect to which the Loan Parties own any executive rights (and Properties unitized therewith) have been maintained, operated and developed in a good and workmanlike manner and in conformity with all Governmental Requirements and in conformity with the provisions of all leases, subleases or other contracts comprising a part of the Hydrocarbon Interests and other contracts and agreements forming a part of such Oil and Gas Properties. Specifically in connection with the foregoing, except for those as could not be reasonably expected to have a Material Adverse Effect, (i) no such Oil and Gas Property is subject to having allowable production reduced below the full and regular allowable (including the maximum permissible tolerance) because of any overproduction (whether or not the same was permissible at the time) and (ii) none of the wells comprising a part of such Oil and Gas Properties (or Properties unitized therewith) is deviated

 

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from the vertical more than the maximum permitted by Governmental Requirements, and such wells are, in fact, bottomed under and are producing from, and the well bores are wholly within, the Oil and Gas Properties (or in the case of wells located on Properties unitized therewith, such unitized Properties). All pipelines, wells, gas processing plants, platforms and other material improvements, fixtures and equipment with respect to which the Loan Parties own any executive rights and that are necessary to conduct normal operations are being or, in the case of such pipelines, wells, gas processing plants, platforms and other material improvements, fixtures and equipment the maintenance of which is performed by a third-party operator, the Borrower is using its commercially reasonable efforts to cause such items to be, and to the Borrower’s knowledge such items are, maintained in a state adequate to conduct normal operations (other than those the failure of which to maintain in accordance with this Section 7.17 could not reasonably be expected to have a Material Adverse Effect).

Section 7.18    Gas Imbalances, Prepayments. To the extent the Loan Parties take Hydrocarbons attributable or allocable to their Oil and Gas Properties in-kind, except as set forth on Schedule 7.18 or on the most recent certificate delivered pursuant to Section 8.12(c), on a net basis there are no gas imbalances, take or pay or other prepayments which would require the Loan Parties to deliver Hydrocarbons produced from their Oil and Gas Properties at some future time without then or thereafter receiving full payment therefor exceeding one half bcf of gas (on an mcf equivalent basis) in the aggregate.

Section 7.19    Marketing of Production. To the extent the Loan Parties take Hydrocarbons attributable or allocable to their Oil and Gas Properties in-kind, except for contracts listed and in effect on the Effective Date on Schedule 7.19, and thereafter either disclosed in writing to the Administrative Agent or included in the most recently delivered Reserve Report (with respect to all of which contracts the Borrower represents that it or the other Loan Parties are receiving a price for all production sold thereunder which is computed substantially in accordance with the terms of the relevant contract and are not having deliveries curtailed substantially below the subject Property’s delivery capacity), no material agreements exist which are not cancelable on 60 days’ notice or less without penalty or detriment for the sale of production from the Loan Parties’ Hydrocarbons (including, without limitation, calls on or other rights to purchase, production, whether or not the same are currently being exercised) that (a) pertain to the sale of production at a fixed price and (b) have a maturity or expiry date of longer than six (6) months.

Section 7.20    Swap Agreements and Qualified ECP Counterparty. Schedule 7.20, as of the Effective Date, and after the Effective Date, each report required to be delivered by the Borrower pursuant to Section 8.01(f), as of the date of (or as of the date(s) otherwise set forth in) such report, sets forth, a true and complete list of all Swap Agreements of the Loan Parties, the material terms thereof (including the type, term, effective date, termination date and notional amounts or volumes), the estimated net mark to market value thereof, all credit support agreements relating thereto other than the Loan Documents (including any margin required or supplied) and the counterparty to each such agreement. The Borrower is a Qualified ECP Counterparty.

Section 7.21    Use of Loans and Letters of Credit. The proceeds of the Loans and the Letters of Credit shall be used (a) for working capital, for exploration and production operations, and for other general company purposes of the Loan Parties, including the acquisition of Oil and Gas Properties, (b) to pay fees, costs and expenses associated with the Transactions and (c) on the

 

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Effective Date to fund the Effective Date Refinancing. The Loan Parties are not engaged principally, or as one of its or their important activities, in the business of extending credit for the purpose, whether immediate, incidental or ultimate, of buying or carrying margin stock (within the meaning of Regulation T, U or X of the Board). No part of the proceeds of any Loan or Letter of Credit will be used for any purpose which violates the provisions of Regulations T, U or X of the Board.

Section 7.22    Solvency. After giving effect to the Transactions and the other transactions contemplated hereby, (a) the aggregate assets (after giving effect to amounts that could reasonably be expected to be received by reason of indemnity, offset, insurance or any similar arrangement), at a fair valuation, of the Loan Parties, taken as a whole, exceed the aggregate Debt of the Loan Parties on a consolidated basis, (b) each of the Loan Parties has not incurred and does not intend to incur, and does not believe that it will incur, Debt beyond its ability to pay such Debt (after taking into account the timing and amounts of cash reasonably expected to be received by each of the Loan Parties and the amounts to be payable on or in respect of its liabilities, and giving effect to amounts that could reasonably be expected to be received by reason of indemnity, offset, insurance or any similar arrangement), as such Debt becomes absolute and matures and (c) each of the Loan Parties does not have (and does not have reason to believe that it will have thereafter) unreasonably small capital for the conduct of its business.

Section 7.23    International Operations. None of the Loan Parties own, and have not acquired or made any other expenditure (whether such expenditure is capital, operating or otherwise) in or related to, any Oil and Gas Properties located outside of the geographical boundaries of the United States or the offshore state or federal waters of the United States of America.

Section 7.24    USA PATRIOT; AML Laws; Anti-Corruption Laws and Sanctions. The Borrower has implemented and maintains in effect policies and procedures, if any, as it reasonably deems appropriate, in light of its business and international activities (if any), designed to ensure compliance by the Borrower, its Subsidiaries and their respective directors, officers, employees and agents with the USA PATRIOT Act, Anti-Corruption Laws, AML Laws and applicable Sanctions. The Loan Parties, their Subsidiaries and their respective officers and employees, and to the knowledge of the Borrower, its directors and agents, are in compliance with the USA PATRIOT Act, Anti-Corruption Laws, AML Laws and applicable Sanctions in all material respects. None of (a) the Loan Parties, any Subsidiary or any of their respective directors, officers or employees, or (b) to the knowledge of the Borrower, any agent of the Loan Parties, or any Subsidiary or other Affiliate that will act in any capacity in connection with or benefit from the credit facility established hereby, (i) is a Sanctioned Person or (ii) is in violation of AML Laws, Anti-Corruption Laws, or applicable Sanctions. No Borrowing or Letter of Credit, use of proceeds or other transaction contemplated by this Agreement will cause a violation of AML Laws, Anti-Corruption Laws or applicable Sanctions. Neither the Loan Parties nor any of their Subsidiaries or any Guarantor, or, to the knowledge of such Borrower, any other Affiliate, has engaged in or intends to engage in any dealings or transactions with, or for the benefit of, any Sanctioned Person or with or in any Sanctioned Country.

Section 7.25    Affected Financial Institution. No Loan Party is subject to the Write-Down and Conversion Powers of any Resolution Authority.

 

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ARTICLE VIII

AFFIRMATIVE COVENANTS

The Borrower covenants and agrees with Lenders that on the Effective Date and thereafter, until Payment in Full:

Section 8.01    Financial Statements; Other Information. The Borrower will furnish to the Administrative Agent for delivery to each Lender:

(a)    Annual Financial Statements. As soon as available, but in any event in accordance with then applicable law and not later than 90 days after the end of each fiscal year of the Borrower, commencing with the fiscal year ending December 31, 2022, its audited consolidated balance sheet and related statements of operations, members’ equity and cash flows as of the end of and for such year, setting forth in each case in comparative form the figures for the previous fiscal year, all reported on by KPMG LLP or other independent public accountants of recognized national standing or otherwise acceptable to the Administrative Agent (without a “going concern” or like qualification or exception and without any qualification or exception as to the scope of such audit (other than a “going concern” or other qualification or exception that results solely from (i) the Maturity Date or the maturity date of any other Debt being scheduled to occur within one year from the time such opinion is delivered, (ii) any potential inability to satisfy any financial covenant in this Agreement or in any other documentation governing Debt permitted under Section 9.02 on a future date or in a future period or (iii) the activities, operations, financial results, assets or liabilities of any Unrestricted Subsidiary)) to the effect that such consolidated financial statements present fairly in all material respects the financial condition and results of operations of the Borrower and its Consolidated Restricted Subsidiaries on a consolidated basis in accordance with GAAP consistently applied (other than changes pursuant to Section 1.05). Notwithstanding the foregoing, the obligations set forth in this Section 8.01(a) may be satisfied with respect to the delivery of financial statements of the Borrower and its Consolidated Restricted Subsidiaries by furnishing to the Administrative Agent and each Lender: (A) the Parent’s audited consolidated balance sheet and related statements of operations, partners’ equity and cash flows as of the end of and for such year, setting forth in each case, where available, in comparative form the figures for the previous fiscal year, all reported on by KPMG LLP or other independent public accountants of recognized national standing or otherwise acceptable to the Administrative Agent (without a “going concern” or like qualification or exception and without any qualification or exception as to the scope of such audit (other than a “going concern” or other qualification or exception that results solely from (A) (i) the Maturity Date or the maturity date of any other Debt permitted under Section 9.02 being scheduled to occur within one year from the time such opinion is delivered, (ii) any potential inability to satisfy any financial covenant in this Agreement or in any other documentation governing Debt permitted under Section 9.02 on a future date or in a future period or (iii) the activities, operations, financial results, assets or liabilities of any Unrestricted Subsidiary)) to the effect that such consolidated financial statements present fairly in all material respects the financial condition and results of operations of such Person and its consolidated subsidiaries on a consolidated basis in accordance with GAAP consistently applied (other than changes pursuant to Section 1.05) and (B) concurrently with the financial information required by this clause (a), consolidating information that explains in reasonable detail the differences between the information relating to the Parent and its Consolidated Subsidiaries, on the one hand, and the information relating to the Borrower and its Consolidated Restricted

 

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Subsidiaries, on the other hand. For the purpose of determining EBITDA of the Parent and its Consolidated Restricted Subsidiaries pursuant to this Section 8.01(a), each reference to the Borrower and its Consolidated Restricted Subsidiaries or the Borrower and/or its Restricted Subsidiaries in the definition of EBITDA and in the definition of Consolidated Net Income shall be deemed to be a reference to the Parent and its Consolidated Subsidiaries or to the Parent and/or its subsidiaries, as the case may be.

(b)    Quarterly Financial Statements. As soon as available, but in any event in accordance with then applicable law and not later than 45 days after the end of each of the first three fiscal quarters of each fiscal year of the Borrower, commencing with the fiscal quarter ending September 30, 2022, its consolidated balance sheet and related statements of operations, members’ equity and cash flows as of the end of and for such fiscal quarter and the then elapsed portion of the fiscal year, setting forth in each case, where available, in comparative form the figures for the corresponding period or periods of (or, in the case of the balance sheet, as of the end of) the previous fiscal year, all certified by one of its Financial Officers as presenting fairly in all material respects the financial condition and results of operations of the Borrower and the Consolidated Restricted Subsidiaries on a consolidated basis in accordance with GAAP consistently applied (other than changes pursuant to Section 1.05), subject to normal year-end audit adjustments and the absence of footnotes. Notwithstanding the foregoing, the obligations set forth in this Section 8.01(b) may be satisfied with respect to the delivery of financial statements of the Borrower and its Consolidated Restricted Subsidiaries by furnishing to the Administrative Agent and each Lender: (A) the Parent’s consolidated balance sheet and related statements of operations, partners’ equity and cash flows as of the end of and for such fiscal quarter and the then elapsed portion of the fiscal year, setting forth in each case in comparative form the figures for the corresponding period or periods of (or, in the case of the balance sheet, as of the end of) the previous fiscal year, all certified by a Financial Officer as presenting fairly in all material respects the financial condition and results of operations of the Parent and its consolidated subsidiaries on a consolidated basis in accordance with GAAP consistently applied (other than changes pursuant to Section 1.05), subject to normal year-end audit adjustments and the absence of footnotes, and (B) concurrently with the financial information required by this clause (b), consolidating information that explains in reasonable detail the differences between the information relating to the Parent and its Consolidated Subsidiaries, on the one hand, and the information relating to the Borrower and its Consolidated Restricted Subsidiaries, on the other hand. For the purpose of determining EBITDA of the Parent and its Consolidated Subsidiaries pursuant to this Section 8.01(b), each reference to the Borrower and its Consolidated Restricted Subsidiaries or the Borrower and/or its Restricted Subsidiaries in the definition of EBITDA and in the definition of Consolidated Net Income shall be deemed to be a reference to the Parent and its Consolidated Subsidiaries or the Parent and/or its subsidiaries, as the case may be.

(c)    Certificate of Financial Officer — Compliance. Concurrently with any delivery of financial statements under Section 8.01(a) or Section 8.01(b), commencing with the delivery of financial statements for the fiscal quarter ending September 30, 2022, a certificate of a Financial Officer in substantially the form of Exhibit D hereto or otherwise acceptable to the Administrative Agent in its sole discretion (i) certifying as to whether a Default has occurred and, if a Default has occurred, specifying the details thereof and any action taken or proposed to be taken with respect thereto, (ii) setting forth reasonably detailed calculations demonstrating compliance with Section 9.01, (iii) stating whether any change in GAAP or in the application

 

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thereof has occurred since the date of the audited financial statements most recently delivered pursuant to Section 8.01(a), and (iv) (A) specifying each Material Subsidiary and each Immaterial Subsidiary (together with, in the event of a change from the last information delivered, a reasonably detailed explanation of the reason each such Subsidiary constitutes a Material Subsidiary or an Immaterial Subsidiary, as the case may be) and (B) to the extent necessary pursuant to the definition of “Material Subsidiary”, designating sufficient additional Restricted Subsidiaries as Material Subsidiaries so as to comply with the definition of “Material Subsidiary”.

(d)    [Reserved].

(e)    Annual Cash Flow Forecast. Concurrently with any delivery of each Reserve Report pursuant to Section 8.12(a), (i) an annual cash flow forecast for the Loan Parties for the then-current fiscal year (prepared in a form customarily used by the Borrower’s senior management) and (ii) if requested by the Administrative Agent, such other customary information related to such cash flow forecast as may be so reasonably requested by the Administrative Agent.

(f)    Certificate of Financial Officer – Swap Agreements. Concurrently with any delivery of financial statements under Section 8.01(a) and Section 8.01(b), a certificate of a Financial Officer, in form and substance satisfactory to the Administrative Agent, setting forth as of a recent date, a true and complete list of all Swap Agreements of the Loan Parties, the material terms thereof (including the type, term, effective date, termination date and notional amounts or volumes), the estimated net mark-to-market value therefor, any new credit support agreements relating thereto (other than the Loan Documents) not listed on Schedule 7.20, any margin required or supplied under any credit support document, and the counterparty to each such agreement.

(g)    Certificate of Insurer - Insurance Coverage. Concurrently with any delivery of financial statements under Section 8.01(a), a certificate of insurance coverage from each insurer with respect to the insurance required by Section 8.07, in form and substance reasonably satisfactory to the Administrative Agent, and, if requested by the Administrative Agent or any Lender, all copies of the applicable policies.

(h)    Other Reports.

(i)    Promptly upon receipt thereof by the Parent or the Loan Parties (or the board of directors, sole managing member or other governing body of the Loan Parties), a copy of each notice or other correspondence received by the Parent or the Loan Parties (or the board of directors, sole managing member or other governing body of the Loan Parties) from the SEC concerning any material investigation or other material inquiry by the SEC regarding financial or other operational results of the Loan Parties.

(ii)    Promptly upon receipt thereof by the Parent or the Loan Parties (or the board of directors, sole managing member or other governing body of the Loan Parties), a copy of each other report or letter submitted to any Loan Party by independent accountants in connection with any annual, interim or special audit made by them of the books of any Loan Party and the response of such party to such letter or report.

 

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(iii)    With respect to any period for which the financial statements of Parent were delivered in lieu of the financial statements of the Borrower under Section 8.01(a) or Section 8.01(b), promptly upon receipt thereof by the Parent or the Loan Parties (or the board of directors, sole managing member or other governing body of the Loan Parties), a copy of each other report or letter submitted to the Parent by independent accountants in connection with any annual, interim or special audit made by them of the books of the Parent and the response of such party to such letter or report.

(i)    SEC and Other Filings; Reports to Shareholders. Promptly after the same become publicly available, copies of all periodic and other reports, proxy statements and other materials filed by Parent or the Loan Parties with the SEC, or with any national securities exchange, or distributed by Parent or the Loan Parties to its shareholders generally, as the case may be.

(j)    Notices Under Material Instruments. Promptly after the furnishing thereof, copies of any financial statement, report or notice (other than with respect to routine administrative matters) furnished to or by any Person pursuant to the terms of any preferred stock designation, indenture, loan or credit or other similar agreement evidencing Material Debt (including, without limitation, any Permitted Additional Debt Document), other than this Agreement and not otherwise required to be furnished to the Lenders pursuant to any other provision of this Section 8.01.

(k)    Lists of Purchasers. To the extent the Loan Parties take any material amount of Hydrocarbons attributable or allocable to their Oil and Gas Properties in-kind, concurrently with the delivery of any Reserve Report to the Administrative Agent pursuant to Section 8.12, a list of all purchasers of Hydrocarbons with respect to which such in-kind deliveries are taken.

(l)    Notice of Dispositions of Oil and Gas Properties and Liquidation of Swap Agreements. In the event any Loan Party intends to Dispose of any Oil and Gas Properties (other than the leasing of their Oil and Gas Properties or the Disposition of Hydrocarbons in the ordinary course of business) or any Equity Interests in any Restricted Subsidiary that owns Oil and Gas Properties, in each case in accordance with Section 9.12(d) or Section 9.12(l), at least ten (10) Business Days’ (or such shorter time as the Administrative Agent may agree in its sole discretion) prior written notice of such Disposition, the price thereof and the anticipated date of closing and any other material details thereof (including title information, reserve engineering information and legal descriptions) reasonably requested by the Administrative Agent or any Lender. In the event that any Loan Party receives any notice of early termination of any Swap Agreement to which it is a party from any of its counterparties, or any Swap Agreement to which any Loan Party is a party is Liquidated, prompt written notice of the receipt of such early termination notice or such Liquidation, (and in the case of a voluntary Liquidation of any Swap Agreement, no less than three (3) Business Days’ (or such shorter time as the Administrative Agent may agree in its sole discretion) prior written notice thereof), as the case may be, together with a reasonably detailed description or explanation thereof and any other details thereof requested by the Administrative Agent or any Lender.

(m)    Notice of Casualty Events. Prompt written notice, and in any event within five Business Days (or such longer time as the Administrative Agent may agree in its sole discretion) of the Borrower becoming aware of the occurrence of any Casualty Event reducing (or constituting a Disposition of) the fair market value of the Property of the Loan Parties by an amount in excess of the greater of (x) $7,500,000 or (y) 5.0% of the then-effective Borrowing Base or the

 

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commencement of any action or proceeding that could reasonably be expected to result in a Casualty Event reducing (or constituting a Disposition of) the fair market value of the Property of the Loan Parties by an amount in excess of the greater of (x) $7,500,000 or (y) 5.0% of the then-effective Borrowing Base.

(n)    Information Regarding the Borrower and Guarantors. (i) Five (5) days’ prior written notice (or such shorter time as the Administrative Agent may agree in its sole discretion) of any change (A) in the Borrower’s or any Guarantor’s corporate name or (B) in the Borrower’s or any Guarantor’s jurisdiction of organization, and (ii) prompt written notice of any change in the Borrower’s or any Guarantor’s federal taxpayer identification number.

(o)    Production Report and Revenue Statements. Concurrently with any delivery of financial statements under Section 8.01(a) or Section 8.01(b), a report setting forth the volume of production and sales attributable to production (and the prices at which such sales were made, the revenues derived from such sales, and the fees, expenses severance taxes and other deductions associated with such sales) with respect to the Oil and Gas Properties of the Loan Parties for each calendar month during the then current fiscal year to date through and including the last day of the fiscal quarter for which financial statements are being delivered, in each case in the form received from third parties or otherwise in the form ordinarily used by management of the Borrower. Without limiting the Borrower’s obligation to deliver the report required by this Section 8.01(o), it is understood and agreed that such report is derived in part from information received from third party operators of the Loan Parties’ Oil and Gas Properties, and as a result thereof, such report may be incomplete with respect to particular Oil and Gas Properties.

(p)    Notices of Certain Changes. Promptly, but in any event within five (5) Business Days after the execution thereof, copies of any amendment, modification or supplement to (i) any Permitted Additional Debt Document or (ii) the certificate or articles of incorporation, bylaws, limited liability company agreement, any preferred stock designation or any other organic document of any Loan Party.

(q)    Notice of Debt Incurrence. Written notice at least three (3) Business Days (or such shorter time as may be agreed to by the Administrative Agent in its sole discretion) prior to the incurrence of any Permitted Additional Debt, the amount thereof, the intended use of proceeds thereof, the anticipated date of closing and available drafts of the offering memorandum (if any) and any other material documents relating to such Permitted Additional Debt.

(r)    Other Requested Information. Promptly following any request therefor, (i) such other information regarding the operations, business affairs and financial condition of any Loan Party (including any Plan and any reports or other information required to be filed with respect thereto under the Code or under ERISA), or compliance with the terms of this Agreement or any other Loan Document, as the Administrative Agent or any Lender may reasonably request or (ii) information and documentation reasonably requested by the Administrative Agent or any Lender for purposes of compliance with applicable “know your customer” requirements under the USA PATRIOT Act, the Beneficial Ownership Regulation or other applicable anti-money laundering laws.

 

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Documents required to be delivered pursuant to Section 8.01(a), (b), (i) or (p) may be delivered electronically and if so delivered shall be deemed delivered on the date on which such documents are posted on the Borrower’s behalf on an Approved Electronic Platform or another relevant Internet or intranet website, if any, to which the Administrative Agent and each Lender have access (whether a commercial, third-party website or whether sponsored by the Administrative Agent). Notwithstanding the foregoing, any delivery of reports or other information required by Section 8.01(a), (b), (i) or (p) shall be deemed to have been delivered on the date on which any such reports or other information have (A) been posted by or on behalf of Parent on the Internet website of the SEC (http://www.sec.gov) or to EDGAR (or such other publicly accessible internet database that may be established and maintained by the SEC as a substitute for or successor to EDGAR) or (B) been posted on Parent’s or the Borrower’s Internet website as previously identified to the Administrative Agent and the Lenders. The Administrative Agent shall have no obligation to maintain paper copies of the documents referred to above, and in any event shall have no responsibility to monitor compliance by the Borrower with any such request by a Lender for delivery, and each Lender shall be solely responsible for timely accessing posted documents and maintaining its copies of such documents.

Section 8.02    Notices of Material Events. The Borrower will furnish to the Administrative Agent and each Lender prompt written notice of the following:

(a)    the occurrence of any Default;

(b)    the filing or commencement of, or the threat in writing of, any action, suit, proceeding, investigation or arbitration by or before any arbitrator or Governmental Authority against or affecting the Borrower or any other Loan Party not previously disclosed in writing to the Lenders or any material adverse development in any action, suit, proceeding, investigation or arbitration (whether or not previously disclosed to the Lenders) that, in either case, if adversely determined, could reasonably be expected to result in a Material Adverse Effect; and

(c)    any other development that results in, or could reasonably be expected to result in, a Material Adverse Effect.

Each notice delivered under this Section 8.02 shall be accompanied by a statement of a Responsible Officer setting forth the material details of the event or development requiring such notice and any action taken or proposed to be taken with respect thereto.

Section 8.03    Existence; Conduct of Business. The Borrower will, and will cause each other Loan Party to, do or cause to be done all things necessary to preserve, renew and keep in full force and effect its legal existence and the rights, licenses, permits, privileges and franchises material to the conduct of its business and maintain, if necessary, its qualification to do business in each other jurisdiction in which its Oil and Gas Properties are located or the ownership of its Properties requires such qualification, except where the failure to so qualify could not reasonably be expected to have a Material Adverse Effect; provided that the foregoing shall not prohibit any merger, consolidation, liquidation or dissolution permitted under Section 9.11.

 

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Section 8.04    Payment of Obligations. The Borrower will, and will cause each of the other Loan Parties to, pay its obligations, including Tax liabilities of the Loan Parties before the same shall become delinquent or in default, except where (a) the validity or amount thereof is being contested in good faith by appropriate proceedings, (b) such Loan Party has set aside on its books adequate reserves with respect thereto in accordance with GAAP and (c) the failure to make payment pending such contest could not reasonably be expected to result in a Material Adverse Effect.

Section 8.05    Performance of Obligations under Loan Documents. The Borrower will pay the Loans and the other Obligations hereunder according to the terms hereof, and the Borrower will, and will cause each other Loan Party to, do and perform every act and discharge all of the obligations to be performed and discharged by them under the Loan Documents, including, without limitation, this Agreement, at the time or times and in the manner specified.

Section 8.06    Operation and Maintenance of Properties. Except, in each case, where the failure to comply could not reasonably be expected to have a Material Adverse Effect, the Borrower, at its own expense, will, and will cause each other Loan Party to:

(a)    to the extent any Loan Party owns any executive rights with respect thereto, operate its Oil and Gas Properties and other material Properties or cause such Oil and Gas Properties and other material Properties to be operated in a careful and efficient manner in accordance with the practices of the industry and in compliance with all applicable contracts and agreements and in compliance with all Governmental Requirements, including, without limitation, applicable proration requirements, and all applicable laws, rules and regulations of every other Governmental Authority from time to time constituted to regulate the development and operation of its Oil and Gas Properties and the production and sale of Hydrocarbons and other minerals therefrom;

(b)    to the extent any Loan Party owns any executive rights with respect thereto, preserve, maintain and keep in good repair, working order and efficiency (ordinary wear and tear excepted) all of such material Oil and Gas Properties and other material Properties, including, without limitation, all equipment, machinery and facilities;

(c)    to the extent any Loan Party owns any executive rights with respect thereto, promptly pay and discharge, or make reasonable and customary efforts to cause to be paid and discharged, all delay rentals, royalties, expenses and indebtedness accruing under the leases or other agreements affecting or pertaining to such Oil and Gas Properties and will do all other things necessary to keep unimpaired their rights with respect thereto and prevent any forfeiture thereof or default thereunder; and

(d)    to the extent any Loan Party owns any executive rights with respect thereto, promptly perform or make reasonable and customary efforts to cause to be performed, in accordance with customary industry standards, the obligations required by each and all of the assignments, deeds, leases, sub-leases, contracts and agreements affecting its interests in such Oil and Gas Properties and other material Properties.

(e)    With respect to the Oil and Gas Properties referred to in this Section 8.06 that are operated by any Person other than any Loan Party, to the extent any Loan Party owns any executive rights with respect thereto, such Loan Party shall use commercially reasonable efforts to cause the operator of such Oil and Gas Properties to comply with this Section 8.06 with respect to the Oil and Gas Properties operated by it.

 

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Section 8.07    Insurance. The Borrower will, and will cause each other Loan Party to, maintain, with financially sound and reputable insurance companies, insurance in such amounts and against such risks as are customarily maintained by companies engaged in the same or similar businesses. The lender loss payable clauses or provisions in said insurance policy or policies insuring any of the Collateral shall be endorsed in favor of and made payable to the Administrative Agent as its interests may appear and such policies in respect of such liability insurance shall contain an endorsement naming the Administrative Agent and the Lenders as “additional insureds”. To the extent that the insurer will agree to do so, such policies will also provide that the insurer will endeavor to give at least 30 days prior notice of any cancellation to the Administrative Agent (subject to a shorter period of time for cancellation due to non-payment of premium). Notwithstanding any additional insured or lender loss payee designation on an insurance policy in favor of the Administrative Agent (for the benefit of the Lenders) and regardless of any initial routing of proceeds payable under an applicable insurance policy, the Borrower shall be given such proceeds for application to reinvestment or other permitted purposes hereunder unless an Event of Default has occurred and is continuing.

Section 8.08    Books and Records; Inspection Rights. The Borrower will, and will cause each other Loan Party to, keep proper books of record and account in which full, true and correct entries in conformity with GAAP are made of all dealings and transactions in relation to its business and activities. The Borrower will, and will cause each other Loan Party to, permit any representatives designated by the Administrative Agent or any Lender, upon reasonable prior written notice, to visit and inspect its Properties (provided that any such representative shall agree to comply with Borrower’s safety rules), to examine and make extracts from its books and records, and to discuss its affairs, finances and condition with its officers and independent accountants, all at such reasonable times and as often as reasonably requested; provided that so long as no Event of Default has occurred and is continuing, the Borrower shall not be required to reimburse the Administrative Agent and the Lenders for more than one inspection during any fiscal year, in the aggregate.

Section 8.09    Compliance with Laws. The Borrower will, and will cause each other Loan Party to, comply with all laws, rules, regulations and orders of any Governmental Authority applicable to it or its Property, except (other than with respect to Anti-Corruption Laws, applicable AML Laws and applicable Sanctions) where the failure to do so, individually or in the aggregate, could not reasonably be expected to result in a Material Adverse Effect. The Borrower will maintain in effect and enforce policies and procedures, if any, as it reasonably deems appropriate, in light of its business and international activities (if any), designed to ensure compliance by the Borrower, its Subsidiaries and their respective directors, officers, employees and agents with Anti-Corruption Laws, AML Laws and applicable Sanctions.

Section 8.10    Environmental Matters.

(a)    The Borrower shall, without cost or expense to the Administrative Agent, the Issuing Bank or the Lenders: (i) comply, and shall cause its Properties and operations and each other Loan Party and each other Loan Party’s Properties and operations to comply, with all

 

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applicable Environmental Laws, the breach of which could be reasonably expected to have a Material Adverse Effect; (ii) not Release or threaten to Release, and shall cause each Subsidiary not to Release or threaten to Release, any Hazardous Material on, under, about or from any Loan Party’s Properties or any other property offsite the Property to the extent caused by any Loan Party’s operations except in compliance with applicable Environmental Laws, the Release or threatened Release of which could reasonably be expected to have a Material Adverse Effect; and (iii) timely obtain or file, and shall cause each other Loan Party to timely obtain or file, all Environmental Permits, if any, required under applicable Environmental Laws to be obtained or filed in connection with the operation or use of any Loan Party’s Properties, which failure to obtain or file could reasonably be expected to have a Material Adverse Effect.

(b)    The Borrower will promptly, but in no event later than five days of the occurrence thereof, notify the Administrative Agent and the Lenders in writing of any threatened action, investigation or inquiry by any Governmental Authority or any threatened demand or lawsuit by any Person against any Loan Party or their respective Properties of which the Borrower has knowledge in connection with any Environmental Laws if the Borrower could reasonably anticipate that such action will result in liability (whether individually or in the aggregate) in excess of the greater of (x) $7,500,000 or (y) 5.0% of the then-effective Borrowing Base, not fully covered by insurance, subject to normal deductibles.

Section 8.11    Further Assurances.

(a)    The Borrower at its sole expense will, and will cause each other Loan Party to, promptly execute and deliver to the Administrative Agent all such other documents, agreements and instruments reasonably requested by the Administrative Agent to comply with, cure any defects or accomplish the conditions precedent, covenants and agreements of any Loan Party in the Loan Documents, including the Notes, or to further evidence and more fully describe the collateral intended as security for the Obligations, or to correct any omissions in this Agreement or the Security Instruments, or to state more fully the obligations secured therein, or to perfect, protect or preserve any Liens created pursuant to this Agreement or any of the Security Instruments or the priority thereof, or to make any recordings, file any notices or obtain any consents, all as may be reasonably necessary or appropriate, in the sole discretion of the Administrative Agent, in connection therewith.

(b)    The Borrower hereby authorizes the Administrative Agent to file one or more financing or continuation statements, and amendments thereto, relative to all or any part of the Collateral without the signature of the Borrower or any other Guarantor where permitted by law. A carbon, photographic or other reproduction of the Security Instruments or any financing statement covering the Collateral or any part thereof shall be sufficient as a financing statement where permitted by law. The Borrower acknowledges and agrees that any financing statement may describe the Collateral as “all assets” of the applicable Borrower or Guarantor or words of similar effect as may be required by the Administrative Agent.

 

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Section 8.12    Reserve Reports.

(a)    On or before March 1st and September 1st of each year, commencing September 1, 2022, the Borrower shall furnish to the Administrative Agent and the Lenders a Reserve Report evaluating the proved Oil and Gas Properties of the Loan Parties as of the immediately preceding January 1st and July 1st, respectively. The Reserve Report as of January 1 of each year shall be prepared by one or more Approved Petroleum Engineers, and the July 1 Reserve Report of each year shall be prepared by one or more Approved Petroleum Engineers or by or under the supervision of the chief engineer of the Borrower who shall certify such Reserve Report to be true and accurate in all material respects and, except as otherwise specified therein, to have been prepared in all material respects in accordance with the procedures used in the immediately preceding January 1 Reserve Report.

(b)    In the event of an Interim Redetermination, the Borrower shall furnish to the Administrative Agent and the Lenders a Reserve Report prepared by or under the supervision of the chief engineer of the Borrower who shall certify such Reserve Report to be true and accurate in all material respects and to have been prepared in accordance with the procedures used in the immediately preceding January 1 Reserve Report. For any Interim Redetermination requested by the Administrative Agent or the Borrower pursuant to Section 2.07(c), the Borrower shall provide such Reserve Report with an “as of” date as required by the Administrative Agent as soon as possible, but in any event no later than thirty (30) days following the receipt of such request.

(c)    With the delivery of each Reserve Report, the Borrower shall provide to the Administrative Agent and the Lenders a certificate from a Responsible Officer certifying that in all material respects: (i) the information contained in the Reserve Report and any other information delivered in connection therewith is true and correct in all material respects, it being understood and agreed that projections concerning volumes attributable to the Oil and Gas Properties of the Loan Parties and production and cost estimates contained in the Reserve Report are necessarily based upon professional opinions, estimates and projections and that the Loan Parties do not warrant that such opinions, estimates and projections will ultimately prove to have been accurate, (ii) except as set forth on an exhibit to the certificate, the Loan Parties own good and defensible title to the Oil and Gas Properties evaluated in such Reserve Report and such Properties are free of all Liens except for Liens permitted by Section 9.03, (iii) except as set forth on an exhibit to the certificate, to the extent the Loan Parties take Hydrocarbons attributable or allocable to their Oil and Gas Properties in-kind, on a net basis there are no gas imbalances, take or pay or other prepayments in excess of the volume specified in Section 7.18 with respect to its Oil and Gas Properties evaluated in such Reserve Report which would require any Loan Party to deliver Hydrocarbons either generally or produced from such Oil and Gas Properties at some future time without then or thereafter receiving full payment therefor; (iv) to the extent Loan Parties take Hydrocarbons attributable or allocable to their Oil and Gas Properties in-kind, attached to the certificate is a list of all marketing agreements entered into subsequent to the later of the Effective Date or the most recently delivered Reserve Report which the Borrower could reasonably be expected to have been obligated to list on Schedule 7.19 had such agreement been in effect on the Effective Date and (v) attached thereto is a schedule of the Oil and Gas Properties evaluated by such Reserve Report that are Mortgaged Properties and demonstrating that the total value of such Mortgaged Properties as a percentage of the total value of the total proved Oil and Gas Properties evaluated in such Reserve Report is in compliance with Section 8.14(a).

 

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Section 8.13    Title Information.

(a)    On or before the delivery to the Administrative Agent and the Lenders of each Reserve Report required by Section 8.12(a), the Borrower will deliver title information in form and substance reasonably acceptable to the Administrative Agent covering enough of the Oil and Gas Properties evaluated by such Reserve Report that were not included in the immediately preceding Reserve Report, so that the Administrative Agent shall have received together with title information previously delivered to the Administrative Agent, title information in form and substance reasonably acceptable to the Administrative Agent on at least 85% of the total value of the proved Oil and Gas Properties evaluated by such Reserve Report.

(b)    If the Borrower has provided title information for additional Properties under Section 8.13(a), the Borrower shall, within sixty (60) days (or such longer period as the Administrative Agent may approve in its sole discretion) of notice from the Administrative Agent that title defects or exceptions exist with respect to such additional Properties, either (i) cure any such title defects or exceptions (including defects or exceptions as to priority) which are not permitted by Section 9.03 raised by such information, (ii) substitute acceptable Mortgaged Properties with no title defects or exceptions (provided that Excepted Liens of the type described in clauses (a), (b), (c), (d), (f) and (m) of the definition thereof may exist, but subject to the provisos at the end of such definition) having an equivalent value or (iii) deliver title information in form and substance reasonably acceptable to the Administrative Agent so that the Administrative Agent shall have received, together with title information previously delivered to the Administrative Agent, title information in form and substance reasonably acceptable to the Administrative Agent on at least 85% of the total value of the proved Oil and Gas Properties evaluated by such Reserve Report.

(c)    If the Borrower is unable to cure any title defect requested by the Administrative Agent or the Required Lenders to be cured within the 60-day period (or such longer period as the Administrative Agent may approve in its sole discretion) or the Borrower does not comply with the requirements to provide title information in form and substance reasonably acceptable to the Administrative Agent covering at least 85% of the total value of the proved Oil and Gas Properties evaluated in the most recent Reserve Report, such default shall not be a Default, but instead the Administrative Agent and/or the Required Lenders shall have the right to exercise the following remedy in their sole discretion from time to time, and any failure to so exercise this remedy at any time shall not be a waiver as to future exercise of the remedy by the Administrative Agent or the Lenders. To the extent that the Administrative Agent or the Required Lenders are not reasonably satisfied with title to any Mortgaged Property after the 60-day period (or such longer period as the Administrative Agent may approve in its sole discretion) has elapsed, such unacceptable Mortgaged Property shall not count towards the 85% requirement, and the Administrative Agent may send a notice to the Borrower and the Lenders that the then outstanding Borrowing Base shall be reduced by an amount as determined by the Required Lenders to cause the Borrower to be in compliance with the requirement to provide title information in form and substance reasonably acceptable to the Administrative Agent on at least 85% of the total value of the proved Oil and Gas Properties. This new Borrowing Base shall become effective immediately after receipt of such notice.

 

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Section 8.14    Additional Collateral; Additional Guarantors.

(a)    In connection with each redetermination of the Borrowing Base, the Borrower shall review the Reserve Report and the list of current Mortgaged Properties (as described in Section 8.12(c)(v)) to ascertain whether the Mortgaged Properties represent at least 85% of the total value of the proved Oil and Gas Properties evaluated in the most recently completed Reserve Report after giving effect to exploration and production activities, acquisitions and Dispositions. In the event that the Mortgaged Properties do not represent at least 85% of such total value, then the Borrower shall, and shall cause the other Loan Parties to, grant, within thirty (30) days (or such longer period as the Administrative Agent may approve in its sole discretion) of delivery of the certificate required under Section 8.12(c), to the Administrative Agent as security for the Obligations a first-priority Lien (provided that Excepted Liens of the type described in clauses (a), (b), (c), (d), (f) and (m) of the definition thereof may exist, but subject to the provisos at the end of such definition) on additional Oil and Gas Properties not already subject to a Lien of the Security Instruments such that after giving effect thereto, the Mortgaged Properties will represent at least 85% of such total value. All such Liens will be created and perfected by and in accordance with the provisions of deeds of trust, mortgages, security agreements and financing statements or other Security Instruments, all in form and substance reasonably satisfactory to the Administrative Agent and in sufficient executed (and acknowledged where necessary or appropriate) counterparts for recording purposes. In order to comply with the foregoing, if any Restricted Subsidiary places a Lien on its Oil and Gas Properties pursuant to this Section 8.14(a) and such Restricted Subsidiary is not a Guarantor, then it shall become a Guarantor and comply with Section 8.14(b).

(b)    If (i) the Borrower or any Restricted Subsidiary creates or acquires any Material Subsidiary or (ii) any Restricted Subsidiary becomes a Material Subsidiary (whether pursuant to the definition of Material Subsidiary or otherwise), then the Borrower shall cause, or shall cause its Restricted Subsidiaries to, promptly, but in any event no later than ten (10) days after the date of creation or acquisition thereof or the date such Restricted Subsidiary becomes a Material Subsidiary, as the case may be (or such later date as the Administrative Agent may agree in its sole discretion): (A) cause such Restricted Subsidiary to become a Guarantor by executing and delivering to the Administrative Agent a duly executed supplement to the Guarantee Agreement (or such other document as the Administrative Agent shall deem appropriate for such purpose), (B) pledge all of the Equity Interests of such Restricted Subsidiary (including, without limitation, delivery of original stock certificates evidencing the Equity Interests of such Restricted Subsidiary, together with an appropriate undated stock power for each certificate duly executed in blank by the registered owner thereof, if applicable) and (C) execute and deliver such other additional closing documents, certificates and legal opinions as shall reasonably be requested by the Administrative Agent.

Section 8.15    ERISA Event. The Borrower will promptly furnish and will cause the other Loan Parties to promptly notify the Administrative Agent upon becoming aware of the occurrence of any ERISA Event that could reasonably be expected to result in material liability to any Loan Party. Such notice shall specify the nature of the ERISA Event, what action such Loan Party or the ERISA Affiliate is taking or proposes to take with respect thereto.

Section 8.16    Marketing Activities. To the extent the Loan Parties take Hydrocarbons attributable or allocable to their Oil and Gas Properties in-kind, the Borrower will not, and will not permit any of the other Loan Parties to, engage in marketing activities for any Hydrocarbons or

 

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enter into any contracts related thereto other than (a) contracts for the sale of Hydrocarbons scheduled or reasonably estimated to be produced from their proved Oil and Gas Properties during the period of such contract, (b) contracts for the sale of Hydrocarbons scheduled or reasonably estimated to be produced from proved Oil and Gas Properties of third parties during the period of such contract associated with the Oil and Gas Properties of the Loan Parties that any Loan Party has the right to market pursuant to joint operating agreements, unitization agreements or other similar contracts that are usual and customary in the oil and gas business and (c) other contracts for the purchase and/or sale of Hydrocarbons of third parties (i) which have generally offsetting provisions (i.e., corresponding pricing mechanics, delivery dates and points and volumes) such that no “position” is taken and (ii) for which appropriate credit support has been taken to alleviate the material credit risks of the counterparty thereto.

Section 8.17    Accounts.

(a)    The Borrower shall, and shall cause each Guarantor to, cause each of its Deposit Accounts, Securities Accounts and Commodity Accounts at all times to be subject to a Control Agreement; provided that (a) no such Control Agreement shall be required for any Excluded Account and (b) with respect to the Deposit Accounts, Security Accounts and Commodity Accounts maintained by the New Loan Parties as of the Effective Date (the “Specified Bank Accounts”), the Borrower and the Guarantors shall have until September 5, 2022 (as such date may be extended by the Administrative Agent in its sole discretion) (the “Control Agreement Delivery Date”) to deliver Control Agreements covering such accounts.

(b)    Borrower shall use commercially reasonable efforts to instruct all third parties from which any Loan Party receives, or is reasonably expected to receive, Cash Receipts by direct deposit, to make direct deposits of such Cash Receipts into (i) a Deposit Account of a Loan Party in which the Administrative Agent has been granted a first-priority Lien and is subject to a Control Agreement, (ii) prior to the Control Agreement Delivery Date, a Deposit Account of a New Loan Party or (iii) a Deposit Account of a Loan Party which is an Excluded Account (subject to any limitations on amounts described in the definition thereof).

Section 8.18    Unrestricted Subsidiaries. The Borrower:

(a)    will cause the management, business and affairs of each of the Borrower and its Restricted Subsidiaries, on the one hand, and the Unrestricted Subsidiaries, on the other hand, to be conducted in such a manner (including by keeping separate books of account, furnishing separate financial statements of the Unrestricted Subsidiaries to creditors and potential creditors thereof and by not permitting Properties of the Borrower and its Restricted Subsidiaries, on the one hand, and the Unrestricted Subsidiaries, on the other hand, to be commingled) so that each Unrestricted Subsidiary will be treated as an entity separate and distinct from the Borrower and any Restricted Subsidiary;

(b)    will not permit any of its Restricted Subsidiaries to, incur, assume or suffer to exist any guarantee by the Borrower or such Restricted Subsidiary of, or be or become liable for any Debt of any Unrestricted Subsidiary; and

 

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(c)    will not permit any Unrestricted Subsidiary to hold any Equity Interest in, or any Debt of, the Borrower or any Restricted Subsidiary.

Section 8.19    Post-Closing Matters. The Borrower shall deliver (or cause to be delivered) to the Administrative Agent the items listed on Schedule 8.19, in each case, on or before the dates specified in Schedule 8.19 (or such later date(s) as may be agreed to by the Administrative Agent in its reasonable discretion). Notwithstanding anything to the contrary in this Agreement or any other Loan Document, to the extent that any representation or warranty would be incorrect or any covenant would be breached, in either case, by the non-delivery of an item listed on Schedule 8.19 on a date prior to the date specified in Schedule 8.19 (or such later date(s) as may be agreed to by the Administrative Agent in its reasonable discretion), such incorrectness or breach is waived through the date specified in Schedule 8.19 (or such later date(s) as may be agreed to by the Administrative Agent in its reasonable discretion).

ARTICLE IX

NEGATIVE COVENANTS

The Borrower covenants and agrees with Lenders that, on the Effective Date and thereafter, until Payment in Full:

Section 9.01    Financial Covenants.

(a)    Ratio of Total Net Debt to EBITDA. The Borrower will not permit, as of the last day of any fiscal quarter, commencing with the fiscal quarter ending September 30, 2022, the ratio of (A) Total Net Debt as of such day to (B) EBITDA for the period of four fiscal quarters (or, if applicable, the relevant annualized period determined in accordance with the definition thereof) ending on such day (the “Leverage Ratio”) to be greater than 3.50 to 1.00.

(b)    Current Ratio. The Borrower will not permit, as of the last day of any fiscal quarter, commencing with the fiscal quarter ending September 30, 2022, its ratio of (i) consolidated current assets (including the unused amount of the total Commitments then available to be borrowed, but excluding non-cash assets under FASB ASC 815) to (ii) consolidated current liabilities (excluding non-cash obligations under FASB ASC 815 and current maturities under this Agreement) (the “Current Ratio”) to be less than 1.00 to 1.00.

(c)    Right to Cure. In the event the Borrower fails to comply with the requirements of Section 9.01(a) or Section 9.01(b) as of the last day of any fiscal quarter of the Borrower, then during the period from and including the first day after the last day of such fiscal quarter through and including the 10th Business Day after the date the compliance certificate for such fiscal quarter is required to be delivered pursuant to Section 8.01(c) (such period, the “Cure Period”), the Borrower shall be permitted to cure such failure to comply by requesting that the Leverage Ratio and/or the Current Ratio be recalculated by increasing EBITDA and/or the consolidated current assets for such fiscal quarter by an amount up to the cash proceeds received by the Borrower from a Specified Equity Contribution during the Cure Period (such amount, a “Cure Amount”); provided that (i) the Borrower delivers written notice to the Administrative Agent on or prior to the date of a timely delivered certificate required by Section 8.01(c) that it has elected to cure the failure to comply and clearly setting forth such Specified Equity Contribution

 

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in the computation required by clause (ii) of such Section 8.01(c); (ii) the amount of the Cure Amount added to EBITDA and/or the consolidated current assets shall not be greater than the amount required to cause the Borrower to be in compliance with Section 9.01(a) or Section 9.01(b), as applicable; (iii) any such increase pursuant to this Section 9.01(c) to EBITDA and/or the consolidated current assets for any fiscal quarter shall be applied solely for the purpose of determining compliance or non-compliance with Section 9.01(a) or Section 9.01(b) as of the last day of any Reference Period that includes such fiscal quarter and not for any other purpose under any Loan Document (including any determination of pro forma compliance with the Leverage Ratio for the purposes of making any Restricted Payment or Investment or any other purpose); (iv) (A) there shall be no more than two fiscal quarters during any period of four consecutive fiscal quarters for which the Borrower cures any Leverage Ratio or Current Ratio default by an equity cure and (B) there shall be no more than five fiscal quarters prior to the Maturity Date for which the Borrower cures any Leverage Ratio or Current Ratio default by an equity cure; (v) such increase in EBITDA and/or consolidated current assets shall be taken into account in calculating the Leverage Ratio or Current Ratio for any Reference Period that includes the last fiscal quarter of the four quarter period with respect to which such cure right was exercised; (vi) Total Net Debt as of the last day of any fiscal quarter for which the foregoing cure right is exercised shall not be deemed reduced by the amount of any Specified Equity Contribution made with respect to such fiscal quarter (even if the proceeds of such Specified Equity Contribution are actually used to repay Debt); (vii) for any period during which EBITDA is calculated on an annualized basis in accordance with the definition thereof, any Cure Amount shall be taken into account after multiplying EBITDA by the applicable annualization factor for such fiscal quarter (i.e. the Cure Amount shall not be annualized); and (viii) the same dollars of the Cure Amount may not be applied to both increase EBITDA and increase consolidated current assets if the Borrower elects to cure the failure to comply with both Section 9.01(a) and Section 9.01(b) in the same fiscal quarter (i.e. separate Cure Amounts shall be required for each such cure). If after giving effect to the foregoing recalculation, the Borrower would then be in compliance with Section 9.01(a) or Section 9.01(b), as applicable, the Borrower shall be deemed to have satisfied the requirements of Section 9.01(a) or Section 9.01(b), as applicable, as of the relevant earlier required date of determination with the same effect as though there had been no failure to comply therewith at such date, and the applicable breach or default of such covenant that had occurred shall be deemed cured for the purpose of this Agreement and the other Loan Documents. Neither the Administrative Agent nor any Lender shall exercise the right to accelerate the Loans or terminate the Commitments and none of Administrative Agent, any Lender or any Secured Party shall exercise any right to foreclose on or take possession of the Collateral or exercise any other remedy pursuant to Section 10.02, the other Loan Documents or applicable law prior to the end of the applicable Cure Period solely on the basis of an Event of Default having occurred and continuing under Section 9.01(a) or Section 9.01(b) (except to the extent that the Borrower has confirmed in writing that it does not intend to provide a Specified Equity Contribution); provided that no Lender or Issuing Bank shall be required to make any extension of credit hereunder during the Cure Period unless the Borrower shall have received the Cure Amount.

Section 9.02    Debt. The Borrower will not, and will not permit any other Loan Party to, incur, create, assume or suffer to exist any Debt, except:

(a)    the Obligations arising under the Loan Documents or any guarantee of or suretyship arrangement for the Obligations arising under the Loan Documents;

 

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(b)    Debt under Capital Leases not to exceed the greater of (x) $5,000,000 and (y) 2.5% of the then-effective Borrowing Base;

(c)    Debt associated with worker’s compensation claims, bonds or surety obligations required by Governmental Requirements or by third parties in the ordinary course of business in connection with the operation of, or provision for the abandonment and remediation of, the Oil and Gas Properties;

(d)    intercompany Debt between the Borrower and any Guarantor or between Guarantors to the extent permitted by Section 9.05(d); provided that such Debt is not held, assigned, transferred, negotiated or pledged (other than pursuant to a Security Instrument) to any Person other than the Borrower or one of the Guarantors; and, provided further, that any such Debt owed by either the Borrower or a Guarantor shall be subordinated to the Obligations on terms set forth in the Guarantee Agreement;

(e)    endorsements of negotiable instruments for collection in the ordinary course of business;

(f)    other unsecured Debt not to exceed the greater of (x) $10,000,000 and (y) 7.5% of the then-effective Borrowing Base in the aggregate at any one time outstanding;

(g)    unsecured senior notes or unsecured senior subordinated notes of the Borrower, and any guarantees thereof; provided that: (i) immediately after giving effect to the incurrence of any such Debt, on a pro forma basis, the Leverage Ratio shall not exceed 3.00 to 1.00 (as the Leverage Ratio is recomputed on such date using (A) Total Net Debt outstanding on such date and (B) EBITDA for the four fiscal quarters (or, if applicable, the relevant annualized period determined in accordance with the definition thereof) ending on the last day of the fiscal quarter immediately preceding such date for which financial statements are available (including, if applicable, the Financial Statements)); provided that this clause (i) shall not apply to the incurrence of any such Debt that constitutes a refinancing of other Debt incurred pursuant to this Section 9.02(g) to the extent that the aggregate principal amount of such refinancing Debt does not exceed the then outstanding principal amount of the refinanced Debt other than an increase in the principal amount as a result of fees and expenses related to the refinancing of such Debt; (ii) both immediately before and immediately after giving effect to the incurrence of such Debt and the use of proceeds thereof, no Event of Default has occurred and is continuing or would result therefrom; (iii) such Debt does not have any scheduled principal amortization in excess of 1.0% of the principal amount thereof per annum; (iv) such Debt does not have a scheduled maturity date or a date of mandatory Redemption in full sooner than the date which is 180 days after the Maturity Date; (v) such Debt does not have any mandatory Redemption, tender or sinking fund provisions (other than (A) customary change of control tender offer provisions and (B) customary asset sale tender offer provisions to the extent any amounts required to be Redeemed are permitted by the terms of such Debt to be applied first to the Obligations); (vi) no Loan Party or other Person guarantees such Debt unless such Loan Party or other Person has guaranteed the Obligations pursuant to the Guarantee Agreement; (vii) the terms of such Debt and any guarantees thereof: (A) are not more restrictive, taken as a whole, on the Loan Parties than the terms of this Agreement and the other Loan Documents (other than with respect to any applicable redemption or prepayment premiums, call protections, funding discounts, fees, interest, and other economic

 

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terms), (B) are at least as favorable to the Borrower and the Guarantors as market terms for issuers of similar size and credit quality given the then prevailing market conditions as reasonably determined by the Borrower and (C) do not require (1) the maintenance or achievement of any financial performance standards or (2) other covenants that, in the case of this clause (2), taken as a whole, are more restrictive on the Loan Parties than the terms of this Agreement and the other Loan Documents, other than as a condition to taking specified actions; (viii) if such Debt is senior subordinated Debt, such Debt is expressly subordinate to the payment in full of all of the Obligations on terms and conditions reasonably satisfactory to the Administrative Agent; (ix) the Borrower shall have complied with Section 8.01(q); and (x) the Borrowing Base shall be reduced pursuant to Section 2.07(f) and any mandatory prepayments required pursuant Section 3.04(c)(iii) shall have been made;

(h)    Debt of any Loan Party consisting of obligations to pay insurance premiums; and

(i)    Debt in an aggregate amount not to exceed $1,000,000 representing deferred compensation (whether such deferred compensation is to be cash or stock-based compensation) of employees or directors of the Borrower or its Affiliates incurred in the ordinary course of business or Debt to current or former directors and employees of the Borrower or its Affiliates, their respective estates, spouses or former spouses, to finance the purchase or redemption of Equity Interests permitted by Section 9.04.

Section 9.03    Liens. The Borrower will not, and will not permit any other Loan Party to, create, incur, assume or permit to exist any Lien on any of its Properties (now owned or hereafter acquired), except:

(a)    Liens securing the payment of any Obligations;

(b)    Excepted Liens;

(c)    Liens securing purchase money Debt or Capital Leases permitted by Section 9.02(b) but only on the Property that is the subject of any such Debt or lease, accessions and improvements thereto, insurance thereon, and the proceeds of the foregoing;

(d)    Liens encumbering insurance policies and the proceeds thereof securing the financing of premiums with respect thereto;

(e)    (i) Liens on cash earnest money deposits or escrowed amounts made in connection with a binding purchase agreement to acquire Oil and Gas Properties, in each case to the extent such acquisition is permitted by this Agreement and (ii) Liens on or with respect to utility and similar deposits in the ordinary course of business;

(f)    customary restrictions contained in agreements relating to the Disposition of water assets, surface rights and other Property (excluding cash, Cash Equivalents, Hydrocarbon Interests and Borrowing Base Properties) which is primarily related to the water supply business of KMF Water, LLC, pending such Disposition; provided that (i) such Disposition is permitted pursuant to Section 9.04(h), Section 9.05(j), Section 9.12(i) or Section 9.12(k) and (ii) such restrictions apply only to the Property that is to be Disposed; and

 

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(g)    Liens on Property not constituting Collateral and not otherwise permitted by the foregoing clauses of this Section 9.03; provided that the aggregate principal or face amount of all Debt secured under this Section 9.03(g) shall not exceed the greater of (x) $10,000,000 and (y) 5.0% of the then-effective Borrowing Base in the aggregate at any one time outstanding.

Section 9.04    Restricted Payments. The Borrower will not, and will not permit any other Loan Party to, declare or make, or agree to pay or make, directly or indirectly, any Restricted Payment, return any capital to its Equity Interest holders or make any distribution of its Property to its Equity Interest holders, except:

(a)    the Borrower may declare and pay dividends with respect to its Equity Interests payable solely in additional shares of its Equity Interests (other than Disqualified Capital Stock);

(b)    the Restricted Subsidiaries may declare and pay dividends ratably with respect to their Equity Interests to the Borrower or any Guarantor;

(c)    the Borrower may (i) if no Event of Default under Sections 10.01(a), (b), (h) or (i) exists immediately before and after giving effect to such Restricted Payment, declare and pay Permitted Tax Distributions and (ii) make distributions to any direct or indirect parent (including, as applicable, the Parent) to pay Public Company Compliance costs, operating expenses incurred in the ordinary course of business and other corporate overhead costs and expenses (including, without limitation, administrative, legal, accounting, and similar expenses payable to third parties), which are reasonable and customary and incurred in the ordinary course of business, plus any reasonable and customary indemnification claims made by directors or officers of the Parent, in each case to the extent such expenses and costs are directly attributable to the ownership or operations of the Parent, the Borrower and its Subsidiaries;

(d)    the Borrower may make cash distributions with respect to its Equity Interests to the holders of its Equity Interests so long as (i) such distribution is paid within 60 days after the date of declaration thereof, (ii) as of the date of such declaration, if such distribution had been paid as of such date of declaration, both immediately before, and immediately after giving pro forma effect to, any such distribution, (A) no Event of Default would have occurred and be continuing, (B) no Borrowing Base Deficiency exists or would exist and (C) Liquidity would be equal to or greater than 10% of the total Commitments (i.e., the lesser of (1) the Aggregate Maximum Credit Amounts, (2) the Aggregate Elected Commitment and (3) the then effective Borrowing Base), and (iii) the Leverage Ratio is less than or equal to 3.00 to 1.00 (on a pro forma basis as the Leverage Ratio is recomputed on the date of such declaration using (A) Total Net Debt outstanding on such date and (B) EBITDA for the four fiscal quarters (or, if applicable, the relevant annualized period determined in accordance with the definition thereof) ending on the last day of the fiscal quarter immediately preceding such date for which financial statements are available (including, if applicable, the Financial Statements));

(e)    redemptions in whole or in part of any of its Equity Interests (A) for another class of its Equity Interests or the Equity Interests of its direct or indirect parent entity or (B) with proceeds from substantially concurrent equity contributions or issuances of new Equity Interests; provided that such new Equity Interests contain terms and provisions at least as advantageous to the Lenders in all material respects to their interests as those contained in the Equity Interests redeemed thereby;

 

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(f)    Restricted Payments to repurchase Equity Interests from directors or employees of the Borrower or its Affiliates (or from the estate, family members, spouse or former spouse of directors or employees of the Borrower or its Affiliates) so long as the aggregate amount of repurchases and settlements under this Section 9.04(f) shall not exceed $10,000,000 per fiscal year;

(g)    cash payments in lieu of the issuance of fractional shares of Equity Interests in connection with any dividend, option, split, warrant or combination thereof, or any transaction permitted hereunder; and

(h)    Restricted Payments consisting solely of water assets, surface rights and other Property (excluding cash, Cash Equivalents, Hydrocarbon Interests and Borrowing Base Properties) which is primarily related to the water supply business of KMF Water, LLC.

Section 9.05    Investments, Loans and Advances. The Borrower will not, and will not permit any other Loan Party to, make or permit to remain outstanding any Investments in or to any Person, except that the foregoing restriction shall not apply to:

(a)    [Reserved];

(b)    accounts receivable arising in the ordinary course of business;

(c)    Cash Equivalents;

(d)    Investments (i) made by the Borrower in or to any Person that, prior to or substantially concurrently with the consummation of such Investment, is a Guarantor, or (ii) made by any Restricted Subsidiary in or to the Borrower or any other Person that, prior to or substantially concurrently with the consummation of such Investment, is a Guarantor;

(e)    (i) subject to the limits in Section 9.06, Investments in direct (or indirect through another Loan Party) ownership interests in Oil and Gas Properties and gathering systems related thereto or related to farm-out, farm-in, joint operating, joint venture or area of mutual interest agreements, gathering systems, pipelines or other similar arrangements which are usual and customary in the oil and gas exploration and production or oil and gas minerals business located within the geographic boundaries of the United States of America or the offshore state or federal waters of the United States of America and (ii) Investments in Oil and Gas Properties received in exchange for or in replacement of the Specified ORRI disposed of pursuant to Section 9.12(l) pursuant to the terms of the Callon Side Letter so long as Section 3 of the Callon Side Letter was in effect pursuant to the terms of Section 7 of the Callon Side Letter at the time such Investment was made;

(f)    loans or advances to employees, officers, or directors of the Borrower or any of its Affiliates in the ordinary course of business of the Borrower, in each case only as permitted by applicable law, including Section 402 of the Sarbanes Oxley Act of 2002, but in any event not to exceed $5,000,000 in the aggregate at any time;

 

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(g)    Investments in stock, obligations or securities received in settlement of debts arising from Investments permitted under this Section 9.05 owing to the Borrower or any other Loan Party as a result of a bankruptcy or other insolvency proceeding of the obligor in respect of such debts or upon the enforcement of any Lien in favor of the Borrower or any other Loan Party; provided that the Borrower shall give the Administrative Agent prompt written notice in the event that the aggregate amount of all Investments held at any one time under this Section 9.05(g) exceeds $1,000,000;

(h)    other Investments not to exceed the greater of (x) $10,000,000 and (y) 7.5% of the then-effective Borrowing Base in the aggregate at any time;

(i)    additional Investments so long as (i) both immediately before, and immediately after giving pro forma effect to, any such Investment, (A) no Event of Default would have occurred and be continuing, (B) no Borrowing Base Deficiency exists or would exist and (C) Liquidity would be equal to or greater than 10% of the total Commitments (i.e., the lesser of (1) the Aggregate Maximum Credit Amounts, (2) the Aggregate Elected Commitment and (3) the then effective Borrowing Base), and (ii) the Leverage Ratio is less than or equal to 3.00 to 1.00 (on a pro forma basis as the Leverage Ratio is recomputed on the date of such Investment using (A) Total Net Debt outstanding on such date and (B) EBITDA for the four fiscal quarters (or, if applicable, the relevant annualized period determined in accordance with the definition thereof) ending on the last day of the fiscal quarter immediately preceding such date for which financial statements are available (including, if applicable, the Financial Statements));

(j)    Investments made with water assets, surface rights and other Property (excluding cash, Cash Equivalents, Hydrocarbon Interests and Borrowing Base Properties) which is primarily related to the water supply business of KMF Water, LLC;

(k)    loans and advances to any direct or indirect parent in lieu of, and not in excess of, the amount of, Restricted Payments permitted to be made to such Person under Section 9.04(c));

(l)    to the extent constituting Investments, (i) cash earnest money deposits or escrowed amounts made in connection with a binding purchase agreement to acquire Oil and Gas Properties, in each case to the extent such acquisition is permitted by this Agreement and (ii) utility and similar deposits in the ordinary course of business; and

(m)    additional Investments funded entirely by capital contributions received by the Borrower from the holders of its Equity Interests within sixty (60) days prior to the making of any such Investment; provided that (i) no Default, Event of Default or Borrowing Base Deficiency exists immediately before or after giving effect to any such Investment and (ii) after making any such Investment, the Borrower has an unused amount of Commitments in an amount equal to or greater than ten percent (10%) of the total Commitments (i.e., the lesser of (A) the Aggregate Maximum Credit Amounts, (B) the Aggregate Elected Commitment and (C) the then effective Borrowing Base) and (iii) prior to making such Investment, the Borrower delivers a certificate of a Responsible Officer to the Administrative Agent certifying as to the foregoing matters in clauses (i) and (ii) of this proviso and attaching reasonably detailed evidence of the applicable capital contributions related to such Investment.

 

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Section 9.06    Nature of Business; International Operations. The Borrower will not, and will not permit any other Loan Party to, allow any material change to be made in the character of its business as an oil and gas minerals company. From and after the Effective Date, the Borrower will not, and will not permit any other Loan Party to, (a) acquire or make any other expenditure (whether such expenditure is capital, operating or otherwise) in or related to, any Oil and Gas Properties not located within the geographical boundaries of the United States of America or the offshore state or federal waters of the United States of America or (b) form or acquire any Foreign Subsidiaries. Each of the Borrower, the Parent and the GP Pledgor shall at all times remain organized under the laws of the United States of America or any State, territory or possession thereof or the District of Columbia.

Section 9.07    [Reserved].

Section 9.08    Proceeds of Loans; OFAC. The Borrower will not permit the proceeds of the Loans or Letters of Credit to be used for any purpose other than those permitted under (and not prohibited by) Section 7.21. Neither the Borrower nor any Person acting on behalf of the Borrower has taken or will take any action which might cause any of the Loan Documents to violate Regulations T, U or X of the Board, in each case as now in effect or as the same may hereinafter be in effect. If requested by the Administrative Agent, the Borrower will furnish to the Administrative Agent and each Lender a statement to the foregoing effect in conformity with the requirements of FR Form U-1 or such other form referred to in Regulation U, Regulation T or Regulation X of the Board, as the case may be. The Borrower will not request any Borrowing or Letter of Credit, and the Borrower shall not use, and shall ensure that its Subsidiaries and its or their respective directors, officers, employees, Affiliates and agents shall not use, directly or indirectly, the proceeds of any Borrowing or Letter of Credit, or lend, contribute, or otherwise make available such proceeds to any Subsidiary, other Affiliate, joint venture partner or other Person (A) in furtherance of an offer, payment, promise to pay, or authorization of the payment or giving of money, or anything else of value, to any Person in violation of any Anti-Corruption Laws or AML Laws, (B) for the purpose of funding, financing or facilitating any activities, business or transaction of or with any Sanctioned Person, or in any Sanctioned Country, or involving any goods originating in or with a Sanctioned Person or Sanctioned Country or (C) in any manner that would result in the violation of any Sanctions by any Person.

Section 9.09    ERISA Compliance. The Borrower will not, and will not permit any other Loan Party to, at any time, contribute to any Plan or Multiemployer Plan if it could reasonably be expected to result in a Material Adverse Effect or would result in a Lien under ERISA or Code Section 430.

Section 9.10    Sale or Discount of Receivables. Except for receivables obtained by the Borrower or any other Loan Party out of the ordinary course of business or the settlement of joint interest billing accounts in the ordinary course of business or discounts granted to settle collection of accounts receivable or the sale of defaulted accounts arising in the ordinary course of business in connection with the compromise or collection thereof and not in connection with any financing transaction, the Borrower will not, and will not permit any other Loan Party to, discount or sell (with or without recourse) any of its notes receivable or accounts receivable.

 

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Section 9.11    Mergers, Etc. The Borrower will not, and will not permit any other Loan Party to, merge into or with or consolidate with any other Person, or permit any other Person to merge into or consolidate with it, or Dispose of (whether in one transaction or in a series of transactions) all or substantially all of its Property to any other Person (whether now owned or hereafter acquired) (any such transaction, a “consolidation”), or liquidate or dissolve; provided, that so long as no Event of Default has occurred and is then continuing, any Subsidiary may participate in a consolidation with the Borrower (provided that the Borrower shall be the survivor) or any other Guarantor (provided that a Guarantor shall be the survivor, or if a Guarantor is not the survivor, such Person shall become a Guarantor substantially concurrently with the consummation of such consolidation).

Section 9.12 Sale of Properties. The Borrower will not, and will not permit any other Loan Party to, Dispose of any Property (including the Liquidation of any Swap Agreement) except for:

(a)    the sale of Hydrocarbons and the lease of Oil and Gas Properties, in each case in the ordinary course of business;

(b)    farmouts in the ordinary course of business of Oil and Gas Properties consisting solely of undeveloped acreage or undrilled depths to which no proved reserves are attributed in the most recently delivered Reserve Report and assignments in connection with such farmouts or the abandonment, farmout, trade, exchange, lease, sublease or other Disposition in the ordinary course of business of Oil and Gas Properties not containing proved reserves and which are not included in the most recently delivered Reserve Report;

(c)    the Disposition of equipment that is no longer necessary for the business of the Borrower or any such Loan Party or is replaced by equipment of at least comparable value and use;

(d)    the (i) Disposition, other than as provided in clauses (a) through (c), of any Oil and Gas Property or any interest therein or any Restricted Subsidiary owning Oil and Gas Properties or (ii) Liquidation of any Swap Agreement; provided that (A) 75% of the consideration received in respect of such Disposition or Liquidation shall be cash and Cash Equivalents, or, solely with respect to Liquidations, other Swap Agreements permitted by Section 9.18; provided that, with respect to any Disposition, notwithstanding the foregoing requirement of this clause (A) (but, for the avoidance of doubt, subject to the other terms and conditions of this Section 9.12(d)), the Borrower and/or its Restricted Subsidiaries may exchange Hydrocarbon Interests for other Hydrocarbon Interests with the same or better reserve classification, reserve characteristics, reserve lives and decline profiles so long as (1) the aggregate Borrowing Base value, as determined by the Administrative Agent, of all proved Oil and Gas Properties of the Borrower and the Restricted Subsidiaries exchanged for such other proved Oil and Gas Properties during any period between two successive Scheduled Redeterminations does not exceed two percent (2%) of the Borrowing Base then in effect, (2) to the extent that a Borrowing Base Deficiency could result from an adjustment to the Borrowing Base resulting from such Disposition, after the consummation of such Disposition(s), the Borrower shall have received net cash proceeds, or shall have cash on hand, sufficient to eliminate any such potential Borrowing Base Deficiency pursuant to Section 3.04(c)(iii), and (3) substantially contemporaneously with the closing of any such

 

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exchange, the Borrower or the applicable Restricted Subsidiary shall, to the extent the Borrower is not then in compliance with Section 8.13, provide title information reasonably requested by the Administrative Agent with respect to, and, to the extent the Borrower is not then in compliance with Section 8.14, grant a first-priority Lien (provided that Excepted Liens of the type described in clauses (a), (b), (c), (d), (f) and (m) of the definition thereof may exist, but subject to the provisos at the end of such definition) on, any proved Oil and Gas Properties acquired in such exchange pursuant to Security Instruments in form and substance reasonably satisfactory to the Administrative Agent and in sufficient executed (and acknowledged where necessary or appropriate) counterparts for recording purposes; (B) the consideration received in respect of such Disposition or Liquidation shall be equal to or greater than the fair market value of the Oil and Gas Property, interest therein, Restricted Subsidiary or Swap Agreement, as applicable, subject of such Disposition or Liquidation as reasonably determined by a Responsible Officer of the Borrower; (C) the Borrowing Base shall be reduced, effective immediately upon such Disposition or Liquidation, by an amount and to the extent required by Section 2.07(e); and (D) if any such Disposition is of a Restricted Subsidiary owning Oil and Gas Properties, such Disposition shall include all the Equity Interests of such Restricted Subsidiary;

(e)    transfers of Properties from (i) the Borrower and/or its Restricted Subsidiaries to the Borrower and/or any Guarantor; provided that after giving effect thereto, the Loan Parties are in compliance with Section 8.14 without giving effect to any grace periods or times for compliance set forth in such section and (ii) any Restricted Subsidiary that is not a Guarantor to any other Restricted Subsidiary that is not a Guarantor;

(f)    Casualty Events;

(g)    Dispositions of the non-cash portion of consideration (other than any Oil and Gas Properties) received for any Disposition permitted by this Section 9.12; provided that the consideration received in respect of such Disposition shall be cash or Cash Equivalents and for fair market value;

(h)    Restricted Payments permitted by Section 9.04 and Investments permitted by Section 9.05;

(i)    [Reserved];

(j)    Sales, transfers, leases and Dispositions of Properties (other than (i) Dispositions of any Oil and Gas Properties or any interest therein or any Restricted Subsidiary owning Oil and Gas Properties or (ii) Liquidations of Swap Agreements) having a fair market value not to exceed the greater of (x) $10,000,000 and (y) 7.5% of the then-effective Borrowing Base during any 12-month period;

(k)    Dispositions of water assets, surface rights and other Property (excluding cash, Cash Equivalents, Hydrocarbon Interests and Borrowing Base Properties) which is primarily related to the water supply business of KMF Water, LLC; and

(l)    So long as Section 3 of the Callon Side Letter is in effect pursuant to the terms of Section 7 of the Callon Side Letter, Dispositions of the Specified ORRI pursuant to the terms of the Callon Side Letter; provided that (i) substantially contemporaneously with the closing

 

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of any such exchange (or such longer period as the Administrative Agent may agree in writing in its sole discretion), the Borrower or the applicable Restricted Subsidiary shall, to the extent the Borrower is not then in compliance with Section 8.13, provide title information reasonably requested by the Administrative Agent with respect to, and, to the extent the Borrower is not then in compliance with Section 8.14, grant a first-priority Lien (provided that Excepted Liens of the type described in clauses (a), (b), (c), (d), (f) and (m) of the definition thereof may exist, but subject to the provisos at the end of such definition) on, any proved Oil and Gas Properties acquired in such exchange pursuant to Security Instruments in form and substance reasonably satisfactory to the Administrative Agent and in sufficient executed (and acknowledged where necessary or appropriate) counterparts for recording purposes and (ii) the Borrowing Base shall be reduced, effectively immediately upon such Disposition, by an amount and to the extent required by Section 2.07(e).

Section 9.13    Environmental Matters. The Borrower will not, and will not permit any other Loan Party to, cause or knowingly permit any of its Property to be in violation of, or do anything or knowingly permit anything to be done which will subject any such Property to a Release or threatened Release of Hazardous Materials where such violations, Release or threatened Release could reasonably be expected to have a Material Adverse Effect.

Section 9.14    Transactions with Affiliates. Except for (i) payment of Restricted Payments expressly permitted by Section 9.04, (ii) Investments expressly permitted by Sections 9.05(f), (i), (j) or (k) and (iii) transactions related to the separation of water assets, surface rights and other Property (excluding cash, Cash Equivalents, Hydrocarbon Interests and Borrowing Base Properties) which is primarily related to the water supply business of KMF Water, LLC from the Borrower, the Borrower will not, and will not permit any other Loan Party to, enter into any transaction, including, without limitation, any purchase, sale, lease or exchange of Property or the rendering of any service, with any Affiliate (other than transactions between the Borrower and any Guarantor and transactions between Guarantors) unless such transaction is otherwise permitted under this Agreement and is upon fair and reasonable terms no less favorable to it than it would obtain in a comparable arm’s length transaction with a Person not an Affiliate.

Section 9.15    Subsidiaries. The Borrower will not, and will not permit any Restricted Subsidiary to, create or acquire any additional Restricted Subsidiary or designate an Unrestricted Subsidiary as a Restricted Subsidiary unless the Borrower gives written notice to the Administrative Agent of such creation or acquisition and complies with Section 8.14(a). The Borrower shall not, and shall not permit any Restricted Subsidiary to Dispose of any Equity Interests in any Restricted Subsidiary except in compliance with Section 9.12(d) or Section 9.12(e). Neither the Borrower nor any Restricted Subsidiary shall have any Foreign Subsidiaries and there shall be no Restricted Subsidiaries that are not Wholly-Owned Subsidiaries.

Section 9.16    Negative Pledge Agreements; Dividend Restrictions. The Borrower will not, and will not permit any other Loan Party to, create, incur, assume or suffer to exist any contract, agreement or understanding which in any way prohibits or restricts (or which requires the consent of or notice to other Persons in connection therewith): (a) the granting, conveying, creation or imposition of any Lien on any of its Property to secure the Obligations in favor of the Administrative Agent and the Lenders, (b) any Loan Party from paying dividends or making distributions in respect of its Equity Interests to the Borrower or any Guarantor, (c) paying any

 

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Debt owed to the Borrower or any other Loan Party, (d) making loans or advances to, or other Investments in, the Borrower or any other Loan Party, or (e) transferring any of its Property to the Borrower or any other Loan Party; provided that the foregoing shall not apply to restrictions and conditions under (A) this Agreement or the Security Instruments, (B) agreements or arrangements evidencing or related to secured Debt permitted by Section 9.02 and Section 9.03, in each case only to the extent such restriction applies only to the Property securing such Debt, (C) customary restrictions and conditions contained in agreements relating to the Disposition of any Property or Equity Interests permitted under Section 9.12 pending such Disposition, in each case only to the extent such restrictions and conditions apply only to the Property or Equity Interests that is to be sold and (D) customary provisions in leases (other than any Oil and Gas Property) restricting the assignment thereof.

Section 9.17    Gas Imbalances, Take-or-Pay or Other Prepayments. To the extent the Loan Parties take Hydrocarbons attributable or allocable to their Oil and Gas Properties in-kind, the Borrower will not, and will not permit any Restricted Subsidiary to, allow gas imbalances, take-or-pay or other prepayments with respect to the Oil and Gas Properties of the Borrower or any other Loan Party that would require the Borrower or such other Loan Party to deliver Hydrocarbons at some future time without then or thereafter receiving full payment therefor exceeding one half bcf of gas (on an mcf equivalent basis) in the aggregate.

Section 9.18    Swap Agreements.

(a)    The Borrower will not, and will not permit any other Loan Party to, enter into any Swap Agreements with any Person other than (i) (A) Swap Agreements in respect of commodities (including Swap Agreements in respect of commodity basis differentials), (B) with an Approved Counterparty, (C) with a tenor not to exceed 60 months, and (D) the aggregate notional volumes for which (calculated independently for basis differential Swap Agreement volumes and other commodity Swap Agreement volumes) do not exceed, as of the date such Swap Agreement is executed, 85% of the reasonably projected production from total proved, developed, producing Oil and Gas Properties of the Loan Parties evaluated in the Initial Reserve Report or thereafter the Reserve Report most recently delivered pursuant to Section 8.12, for each month following the date such Swap Agreement is entered into, in each case for each of crude oil, natural gas liquids and natural gas, calculated separately and (ii) Swap Agreements in respect of interest rates with an Approved Counterparty effectively converting interest rates from floating to fixed, the notional amounts of which (when aggregated with all other Swap Agreements of the Borrower and the other Loan Parties then in effect effectively converting interest rates from floating to fixed) do not exceed, as of the date such Swap Agreement is entered into, 75% of the then outstanding principal amount of the Borrower’s Debt for borrowed money which bears interest at a floating rate; provided that put option contracts that are not related to corresponding calls, collars or swaps and for which an upfront premium has been paid shall not be included in calculating such percentage threshold. In no event shall any Swap Agreement contain any requirement, agreement or covenant for the Borrower or any other Loan Party to post collateral or margin to secure their obligations under such Swap Agreement or to cover market exposures; provided, however, that the foregoing shall not prohibit or be deemed to prohibit the Secured Swap Obligations from being secured by the Security Instruments.

 

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(b)    If, on the last day of any fiscal quarter, the aggregate notional volumes of all Swap Agreements in respect of commodities to which the Borrower or any other Loan Party is a party for which settlement payments were calculated in such fiscal quarter exceeds 100% of the actual production of Hydrocarbons (for each of crude oil, natural gas liquids and natural gas, calculated separately) from the proved, developed, producing Oil and Gas Properties of the Loan Parties in such fiscal quarter (other than puts, floors, and basis differential swaps on volumes hedged by other Swap Agreements), then the Borrower shall, or shall cause the other Loan Parties to, Liquidate existing Swap Agreements within fifteen (15) Business Days (or such longer period as agreed by the Administrative Agent) after the end of such fiscal quarter, such that, after giving effect to such Liquidation, future hedging notional volumes will not exceed 100% of reasonably projected production of Hydrocarbons (for each of crude oil, natural gas liquids and natural gas, calculated separately) from the proved, developed, producing Oil and Gas Properties of the Loan Parties for the then-current fiscal quarter and any succeeding fiscal quarters.

Section 9.19    Amendments to Material Agreements; Amendment to Fiscal Year.

(a)    The Borrower will not, and will not permit any other Loan Party to, amend, modify or supplement (or enter into any agreement that has the effect of amending, modifying or supplementing) any of its organizational documents in any manner that would be materially adverse to the Lenders.

(b)    The Borrower will, and the Borrower will not permit any other Loan Party to, change its fiscal year to end on a day other than December 31 or change the method of determining its fiscal year.

Section 9.20    Amendments to Terms of the Merger Agreement, Callon Side Letter Assignment and Callon Side Letter. The Borrower will not, and will not permit any other Loan Party to, amend, modify, waive or otherwise change, consent or agree to any amendment, modification, waiver or other change to, any of the terms of the Merger Agreement, the Callon Side Letter Assignment or the Callon Side Letter if the effect thereof would be materially adverse to the Lenders; provided that any direct or indirect amendment to (i) Section 1 of the Callon Side Letter Assignment or (ii) the defined terms (or component terms of) “Permitted Acreage Swap”, “Post-Closing Lease”, “ORRI Lease”, “Fair Market Value” or “Swap Valuation Imbalance” as defined in the Callon Side Letter, or to Section 3 or Section 7 of the Callon Side Letter, shall in each case be deemed materially adverse to the Lenders unless the Administrative Agent agrees in writing that such amendment is not materially adverse to the Lenders.

Section 9.21     Repayment of Permitted Additional Debt; Amendment to Terms of Permitted Additional Debt.

(a)    The Borrower will not, and will not permit any other Loan Party to, call, make or offer to make any optional or voluntary Redemption of, or otherwise optionally or voluntarily Redeem (whether in whole or in part) any Permitted Additional Debt, except that:

(i)    so long as no Event of Default or Borrowing Base Deficiency has occurred and is continuing or would result therefrom, the Borrower may Redeem any Permitted Additional Debt with (A) the net cash proceeds of any newly issued Permitted Additional Debt to

 

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the extent permitted to be incurred pursuant to Section 9.02(g) or (B) the net cash proceeds of any issuance or sale of, or in exchange for, Equity Interests (other than Disqualified Capital Stock) of the Borrower; and

(ii)    the Borrower may Redeem any Permitted Additional Debt in cash so long as (1) such Redemption is made within 30 days after the date of irrevocable notice to the holders or lenders in respect thereof, (2) as of the date of such notice, if such Redemption had been made as of the date of such declaration, both immediately before, and immediately after giving effect to, any such Redemption, (A) no Event of Default shall have occurred and be continuing, (B) no Borrowing Base Deficiency exists or would exist and (C) Liquidity would be equal to or greater than 10% of the total Commitments (i.e., the lesser of (1) the Aggregate Maximum Credit Amounts, (2) the Aggregate Elected Commitment and (3) the then effective Borrowing Base), and (3) the Leverage Ratio is less than or equal to 3.00 to 1.00 (on a pro forma basis as the Leverage Ratio is recomputed on the date of such notice using (A) Total Debt outstanding on such date and (B) EBITDA for the four fiscal quarters (or, if applicable, the relevant annualized period determined in accordance with the definition thereof) ending on the last day of the fiscal quarter immediately preceding such date for which financial statements are available (including, if applicable, the Financial Statements)).

(b)    The Borrower will not, and will not permit any other Loan Party to, amend, modify, waive or otherwise change, consent or agree to any amendment, modification, waiver or other change to, any of the terms of any Permitted Additional Debt or any Permitted Additional Debt Document if: (i) the effect thereof would be to shorten its maturity or average life or increase the amount of any payment of principal thereof or increase the rate or shorten any period for payment of interest thereon or (ii) the effect thereof would be to cause the Borrower to violate the terms of Section 9.02(g).

(c)    With respect to any Permitted Additional Debt that is subordinated to the Obligations or any other Debt, the Borrower will not, and will not permit any other Loan Party to, designate any such Debt (other than obligations of the Loan Parties pursuant to the Loan Documents) as “Specified Senior Indebtedness” or “Specified Guarantor Senior Indebtedness” or give any such other Debt any other similar designation for the purposes of such Permitted Additional Debt Document related to such Permitted Additional Debt that is subordinated to the Obligations or any other Debt.

Section 9.22    Passive Holding Company Status of the Parent and the GP Pledgor. Each of the Parent and the GP Pledgor shall not directly operate any material business; provided that, for the avoidance of doubt, the following (and activities incidental thereto) shall not constitute the operation of a business and shall in all cases be permitted to the extent not otherwise restricted under the terms of this Agreement: (i) its direct and indirect ownership of the Equity Interests of its subsidiaries; (ii) the maintenance of its legal existence (including the ability to incur fees, costs and expenses relating to such maintenance; (iii) any issuance or sale of its Equity Interests (including, for the avoidance of doubt, performing activities in preparation for and consummating any such offering, issuance or sale, the making of any dividend or distribution on account of, or any redemption, retirement, sinking fund or similar payment, purchase or other acquisition for value of, any shares of any class of its Equity Interests) and, in each case, the repurchase or redemption thereof; (iv) financing activities, including the issuance of securities, incurrence of

 

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Debt permitted by this Agreement (provided that no such Debt is secured by Liens on the Equity Interests of the Borrower other than the Liens in favor of the Administrative Agent for the benefit of the Secured Parties permitted under Section 9.03(a)), payment of dividends and making contributions to the capital of any other Loan Party or their respective Subsidiaries, and entrance into Swap Agreements permitted by this Agreement; (v) compliance with applicable law and legal, Tax and accounting and other administrative matters related thereto, including participating in Tax, accounting and other administrative matters as a member of any consolidated, unitary, combined or other similar group, and activities and filing Tax returns and paying Taxes and contesting any Taxes and other customary obligations related thereto in the ordinary course; (vi) performance of activities relating to its officers, directors, managers and employees and those of the Permitted Holders, the Borrower and/or its Subsidiaries, including providing indemnification to such officers, directors, managers or employees; (vii) holding any cash and Cash Equivalents; (viii) holding any other property received by it as a distribution from any the Borrower or any of its Subsidiaries and making further distributions of such property; (ix) holding director and shareholder meetings, preparing organizational records, complying with its organizational documents and other organizational activities required to maintain its separate organizational structure or to comply with applicable Governmental Requirements, including preparing reports to Governmental Authorities or shareholders; (x) entering into and performance of obligations with respect to contracts and other arrangements in connection with the activities contemplated by this Section 9.22; and (xi) any activities incidental to the foregoing or customary for passive holding companies, including, for the avoidance of doubt, entering into transactions otherwise permitted under this Agreement for the direct benefit of the Loan Parties, ownership of immaterial properties and assets incidental to the business or activities described in the foregoing clause and payment of costs and expenses in connection with the business or activities described in the foregoing clauses.

ARTICLE X

EVENTS OF DEFAULT; REMEDIES

Section 10.01    Events of Default. One or more of the following events shall constitute an “Event of Default”:

(a)    the Borrower shall fail to pay any principal of any Loan or any reimbursement obligation in respect of any LC Disbursement when and as the same shall become due and payable, whether at the due date thereof or at a date fixed for prepayment thereof, by acceleration or otherwise;

(b)    the Borrower shall fail to pay any interest on any Loan or any fee or any other amount (other than an amount referred to in Section 10.01(a)) payable under any Loan Document, when and as the same shall become due and payable, and such failure shall continue unremedied for a period of five (5) Business Days;

(c)    any representation or warranty made or deemed made by or on behalf of the Borrower or any other Loan Party in or in connection with any Loan Document or any amendment or modification of any Loan Document or waiver under such Loan Document, or in any report, certificate, financial statement or other document furnished pursuant to or in connection with any Loan Document or any amendment or modification thereof or waiver thereunder, shall prove to have been incorrect in any material respect (unless already qualified by materiality, in which case such applicable representation and warranty shall prove to have been incorrect in any respect) when made or deemed made;

 

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(d)    the Borrower or any other Loan Party shall fail to observe or perform any covenant, condition or agreement applicable to it contained in Section 8.01(n), Section 8.02, Section 8.03, Section 8.13, Section 8.14, Section 8.17, Section 8.18, Section 8.19 or in Article IX.

(e)    the Borrower or any other Loan Party shall fail to observe or perform any covenant, condition or agreement applicable to it contained in this Agreement (other than those specified in Section 10.01(a), Section 10.01(b) or Section 10.01(d)) or any other Loan Document, and such failure shall continue unremedied for a period of 30 days after the earlier to occur of (i) notice thereof from the Administrative Agent to the Borrower (which notice will be given at the request of any Lender) or (ii) a Responsible Officer of the Borrower or such other Loan Party otherwise becoming aware of such default;

(f)    the Borrower or any other Loan Party shall fail to make any payment (whether of principal or interest and regardless of amount) in respect of any Material Debt, when and as the same shall become due and payable and such failure continues after the applicable grace or notice period, if any, specified in the relevant document for such Material Debt;

(g)    any other event or condition occurs that results in any Material Debt becoming due prior to its scheduled maturity or that enables or permits (after giving effect to any applicable notice periods, if any, and any applicable grace periods) the holder or holders of any such Material Debt or any trustee or agent on its or their behalf to cause any such Material Debt to become due, or to require the Redemption thereof or any offer to Redeem to be made in respect thereof, prior to its scheduled maturity or require the Borrower or any other Loan Party to make an offer in respect thereof; provided that this paragraph (g) shall not apply to secured Debt that becomes due solely as a result of the sale or transfer of the property or assets securing such Debt, if such sale or transfer is permitted hereunder and under the documents providing for such Debt;

(h)    an involuntary proceeding shall be commenced or an involuntary petition shall be filed seeking (i) liquidation, reorganization or other relief in respect of the Borrower or any other Loan Party or any of its debts, or of a substantial part of its assets, under any Federal, state or foreign bankruptcy, insolvency, receivership or similar law now or hereafter in effect or (ii) the appointment of a receiver, trustee, custodian, sequestrator, conservator or similar official for the Borrower or any other Loan Party or for a substantial part of its assets, and, in any such case, such proceeding or petition shall continue undismissed for 60 days or an order or decree approving or ordering any of the foregoing shall be entered;

(i)    the Borrower or any other Loan Party shall (i) voluntarily commence any proceeding or file any petition seeking liquidation, reorganization or other relief under any Federal, state or foreign bankruptcy, insolvency, receivership or similar law now or hereafter in effect, (ii) consent to the institution of, or fail to contest in a timely and appropriate manner, any proceeding or petition described in Section 10.01(h), (iii) apply for or consent to the appointment of a receiver, trustee, custodian, sequestrator, conservator or similar official for any of the Borrower or any other Loan Party or for a substantial part of its assets, (iv) file an answer admitting the material allegations of a petition filed against it in any such proceeding, (v) make a general assignment for the benefit of creditors or (vi) take any action for the purpose of effecting any of the foregoing;

 

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(j)    the Borrower or any other Loan Party shall become unable, admit in writing its inability or fail generally to pay its debts as they become due;

(k)    (i) one or more judgments for the payment of money in an aggregate amount in excess of the greater of (x) $22,500,000 and (y) 7.5% of the then-effective Borrowing Base (to the extent not covered by independent third party insurance as to which the insurer does not dispute coverage and is not subject to an insolvency proceeding) or (ii) any one or more non-monetary judgments that have, or could reasonably be expected to have, individually or in the aggregate, a Material Adverse Effect, shall be rendered against the Borrower, any other Loan Party or any combination thereof and the same shall remain undischarged for a period of 60 consecutive days during which execution shall not be effectively stayed, or any action shall be legally taken by a judgment creditor to attach or levy upon any assets of the Borrower or any other Loan Party to enforce any such judgment;

(l)    the Loan Documents after delivery thereof shall for any reason, except to the extent permitted by the terms thereof, (i) cease to be in full force and effect and valid, binding and enforceable in accordance with their terms against the Borrower or any other Loan Party party thereto, other than due to the action or inaction of the Administrative Agent, or shall be repudiated by any of them, or the Borrower, any other Loan Party or any of their Affiliates shall so state in writing or (ii) cease to create a valid and perfected Lien of the priority required thereby on any material portion of the collateral purported to be covered thereby, except to the extent permitted by the terms of this Agreement, or the Borrower, any other Loan Party or any of their Affiliates shall so state in writing; or

(m)    a Change in Control shall occur.

Section 10.02    Remedies.

(a)    In the case of an Event of Default other than one described in Section 10.01(h) or Section 10.01(i), at any time thereafter during the continuance of such Event of Default, the Administrative Agent may with the consent of the Majority Lenders, and at the request of the Majority Lenders, shall, by written notice to the Borrower, take either or both of the following actions, at the same or different times: (i) terminate the Commitments, and thereupon the Commitments shall terminate immediately, and (ii) declare the Notes and the Loans then outstanding to be due and payable in whole (or in part, in which case any principal not so declared to be due and payable may thereafter be declared to be due and payable), and thereupon the principal of the Loans so declared to be due and payable, together with accrued interest thereon and all fees and other obligations of the Borrower and the Guarantors accrued hereunder and under the Notes and the other Loan Documents (including, without limitation, the payment of cash collateral or the making of other backstop arrangements to secure the LC Exposure as provided in Section 2.08(j)), shall become due and payable immediately, without presentment, demand, protest, notice of intent to accelerate, notice of acceleration or other notice of any kind, all of which are hereby waived by the Borrower and each Guarantor; and in case of an Event of Default described in Section 10.01(h) or Section 10.01(i), the Commitments shall automatically terminate

 

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and the Notes and the principal of the Loans then outstanding, together with accrued interest thereon and all fees and the other obligations of the Borrower and the Guarantors accrued hereunder and under the Notes and the other Loan Documents (including, without limitation, the payment of cash collateral or the making of other backstop arrangements to secure the LC Exposure as provided in Section 2.08(j)), shall automatically become due and payable, without presentment, demand, protest or other notice of any kind, all of which are hereby waived by the Borrower and each Guarantor.

(b)    In the case of the occurrence of an Event of Default, the Administrative Agent and the Lenders will have all other rights and remedies available at law and equity.

(c)    All proceeds realized from the liquidation or other Disposition of Collateral or otherwise received after maturity of the Loans or the Notes, whether by acceleration or otherwise, shall be applied:

(i)    first, to payment or reimbursement of that portion of the Obligations constituting fees, expenses and indemnities payable to the Administrative Agent in its capacity as such;

(ii)    second, pro rata to payment or reimbursement of that portion of the Obligations constituting fees, expenses and indemnities payable to the Lenders;

(iii)    third, pro rata to payment of accrued interest on the Loans;

(iv)    fourth, pro rata to payment of (A) principal outstanding on the Loans; (B) reimbursement obligations in respect of Letters of Credit pursuant to Section 2.08(e) (and cash collateralization or backstopping of LC Exposure hereunder); (C) Secured Swap Obligations owing to Secured Swap Parties; and (D) Secured Cash Management Obligations owing to Secured Cash Management Providers;

(v)    fifth, pro rata to any other Obligations; and

(vi)    sixth, any excess, after all of the Obligations shall have been paid in full in cash, shall be paid to the Borrower or as otherwise required by any Governmental Requirement.

(vii)    provided that, for the avoidance of doubt, Excluded Swap Obligations with respect to any Guarantor shall not be paid with amounts received from such Guarantor or its assets, but appropriate adjustments shall be made with respect to payments from the Borrower and any other Guarantors to preserve the allocation to Obligations otherwise set forth above in this Section 10.02(c).

 

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ARTICLE XI

THE AGENTS

Section 11.01    Appointment; Powers.

(a)    Each of the Lenders and the Issuing Bank hereby irrevocably appoints the Administrative Agent as its agent and authorizes the Administrative Agent to take such actions as agent on its behalf and to exercise such powers as are delegated to the Administrative Agent by the terms hereof and the other Loan Documents, together with such actions and powers as are reasonably incidental thereto. Except with respect to Section 11.14, the provisions of this Article are solely for the benefit of the Administrative Agent, the other Agents, the Lenders and the Issuing Bank, and neither the Borrower nor any Guarantor shall have rights as a third party beneficiary of any of such provisions.

(b)    The Administrative Agent shall also act as the “collateral agent” under the Loan Documents, and each of the Lenders (including in its capacities as a potential Secured Swap Party and a potential Secured Cash Management Provider) and the Issuing Bank hereby irrevocably appoints and authorizes the Administrative Agent to act as the agent of such Lender and the Issuing Bank for purposes of acquiring, holding and enforcing any and all Liens on Collateral granted by any of the Borrower and the Guarantors to secure any of the Obligations, together with such powers and discretion as are reasonably incidental thereto. In this connection, the Administrative Agent, as “collateral agent” and any co-agents, sub-agents and attorneys-in-fact appointed by the Administrative Agent pursuant to Section 11.05 for purposes of holding or enforcing any Lien on the Collateral (or any portion thereof granted under the Security Instruments, or for exercising any rights and remedies thereunder at the direction of the Administrative Agent), shall be entitled to the benefits of all provisions of this Article XI and Article XII (including Section 12.03(c), as though such co-agents, sub-agents and attorneys-in-fact were the “collateral agent” under the Loan Documents) as if set forth in full herein with respect thereto.

Section 11.02    Duties and Obligations of Administrative Agent. The Administrative Agent shall not have any duties or obligations except those expressly set forth in the Loan Documents. Without limiting the generality of the foregoing, (a) the Administrative Agent shall not be subject to any fiduciary or other implied duties, regardless of whether a Default has occurred and is continuing (the use of the term “agent” herein and in the other Loan Documents with reference to the Administrative Agent is not intended to connote any fiduciary or other implied (or express) obligations arising under agency doctrine of any applicable law; rather, such term is used merely as a matter of market custom, and is intended to create or reflect only an administrative relationship between independent contracting parties), (b) the Administrative Agent shall have no duty to take any discretionary action or exercise any discretionary powers, except as provided in Section 11.03, (c) except as expressly set forth herein, the Administrative Agent shall not have any duty to disclose, and shall not be liable for the failure to disclose, any credit or other information concerning the business, prospects, operations, property, financial and other condition or creditworthiness of the Borrower or any of its Affiliates, that is communicated to, obtained or in the possession of, the Administrative Agent, Arranger or any of their Related Parties in any capacity, except for notices, reports and other documents expressly required to be furnished to the Lenders by the Administrative Agent herein, (d) shall not be responsible for or have any duty to ascertain or inquire into (i) any statement, warranty or representation made in or in connection with this Agreement or any other Loan Document, (ii) the contents of any certificate, report or other document delivered hereunder or thereunder or in connection herewith or therewith, (iii) the performance or observance of any of the covenants, agreements or other terms or conditions set forth herein or therein or the occurrence of any Default, (iv) the validity, enforceability,

 

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effectiveness or genuineness of this Agreement, any other Loan Document or any other agreement, instrument or document, or the creation, perfection or priority of any Lien purported to be created by the Security Instruments, (v) the value or the sufficiency of any Collateral or (vi) the satisfaction of any condition set forth in Article VI or elsewhere herein, other than to confirm receipt of items expressly required to be delivered to the Administrative Agent and (e) shall not be liable for any action taken or not taken by it (i) with the consent or at the request of the Majority Lenders (or such other number or percentage of the Lenders as shall be necessary, or as the Administrative Agent shall believe in good faith shall be necessary, under the circumstances as provided in Sections 12.02 and 10.02) or (ii) in the absence of its own gross negligence or willful misconduct, as determined by a court of competent jurisdiction by a final and nonappealable judgment. The Administrative Agent shall be deemed not to have knowledge of any Default unless and until written notice thereof is given to the Administrative Agent by the Borrower or a Lender, and shall not be responsible for or have any duty to ascertain or inquire into (i) any statement, warranty or representation made in or in connection with this Agreement or any other Loan Document, (ii) the contents of any certificate, report or other document delivered hereunder or under any other Loan Document or in connection herewith or therewith, (iii) the performance or observance of any of the covenants, agreements or other terms or conditions set forth herein or in any other Loan Document, (iv) the validity, enforceability, effectiveness or genuineness of this Agreement, any other Loan Document or any other agreement, instrument or document, (v) the satisfaction of any condition set forth in Article VI or elsewhere herein, other than to confirm receipt of items expressly required to be delivered to the Administrative Agent or as to those conditions precedent expressly required to be to the Administrative Agent’s satisfaction, (vi) the existence, value, perfection or priority of any collateral security or the financial or other condition of the Borrower and the Subsidiaries or any other obligor or guarantor, or (vii) any failure by the Borrower or any other Person (other than itself) to perform any of its obligations hereunder or under any other Loan Document or the performance or observance of any covenants, agreements or other terms or conditions set forth herein or therein. For purposes of determining compliance with the conditions specified in Article VI, each Lender shall be deemed to have consented to, approved or accepted or to be satisfied with, each document or other matter required thereunder to be consented to or approved by or acceptable or satisfactory to a Lender unless the Administrative Agent shall have received written notice from such Lender prior to the proposed closing date specifying its objection thereto.

Section 11.03    Action by Administrative Agent. The Administrative Agent shall have no duty to take any discretionary action or exercise any discretionary powers, except discretionary rights and powers expressly contemplated hereby or by the other Loan Documents that the Administrative Agent is required to exercise in writing as directed by the Majority Lenders (or such other number or percentage of the Lenders as shall be necessary under the circumstances as provided in Section 12.02), provided that the Administrative Agent shall not be required to take any action that, in its opinion or the opinion of its counsel, may expose the Administrative Agent to liability or that is contrary to any Loan Document or applicable law, including for the avoidance of doubt any action that may be in violation of the automatic stay under any debtor relief law or that may effect a forfeiture, modification or termination of property of a Defaulting Lender in violation of any debtor relief law, and in all cases the Administrative Agent shall be fully justified in failing or refusing to act hereunder or under any other Loan Documents unless it shall (a) receive written instructions from the Majority Lenders (or such other number or percentage of the Lenders as shall be necessary under the circumstances as provided in Section 12.02) specifying the action

 

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to be taken and (b) be indemnified to its satisfaction by the Lenders against any and all liability and expenses which may be incurred by it by reason of taking or continuing to take any such action. The instructions as aforesaid and any action taken or failure to act pursuant thereto by the Administrative Agent shall be binding on all of the Lenders. If a Default has occurred and is continuing, then the Administrative Agent shall take such action with respect to such Default as shall be directed by the requisite Lenders in the written instructions (with indemnities) described in this Section 11.03; provided that, unless and until the Administrative Agent shall have received such directions, the Administrative Agent may (but shall not be obligated to) take such action, or refrain from taking such action, with respect to such Default as it shall deem advisable in the best interests of the Lenders. In no event, however, shall the Administrative Agent be required to take any action which exposes the Administrative Agent to personal liability or which is contrary to this Agreement, the Loan Documents or applicable law. The Administrative Agent shall not be liable for any action taken or not taken by it with the consent or at the request of the Majority Lenders (or such other number or percentage of the Lenders as shall be necessary under the circumstances as provided in Section 12.02), and otherwise the Administrative Agent shall not be liable for any action taken or not taken by it hereunder or under any other Loan Document or under any other document or instrument referred to or provided for herein or therein or in connection herewith or therewith INCLUDING ITS OWN ORDINARY NEGLIGENCE, except for its own gross negligence or willful misconduct.

Section 11.04    Reliance by Administrative Agent. The Administrative Agent shall be entitled to rely upon, and shall not incur any liability for relying upon, any notice, request, certificate, consent, statement, instrument, document or other writing believed by it to be genuine and to have been signed or sent by the proper Person. The Administrative Agent also may rely upon any statement made to it orally or by telephone and believed by it to be made by the proper Person, and shall not incur any liability for relying thereon and each of the Borrower, the Lenders and the Issuing Bank hereby waives the right to dispute the Administrative Agent’s record of such statement, except in the case of gross negligence or willful misconduct by the Administrative Agent. The Administrative Agent may consult with legal counsel (who may be counsel for the Borrower), independent accountants and other experts selected by it, and shall not be liable for any action taken or not taken by it in accordance with the advice of any such counsel, accountants or experts. The Administrative Agent may deem and treat the payee of any Note as the holder thereof for all purposes hereof unless and until a written notice of the assignment or transfer thereof permitted hereunder shall have been filed with the Administrative Agent.

Section 11.05    Subagents. The Administrative Agent may perform any and all its duties and exercise its rights and powers by or through any one or more sub-agents appointed by the Administrative Agent. The Administrative Agent and any such sub-agent may perform any and all its duties and exercise its rights and powers through their respective Related Parties. The exculpatory provisions of the preceding Sections of this Article XI shall apply to any such sub-agent and to the Related Parties of the Administrative Agent and any such sub-agent, and shall apply to their respective activities in connection with the syndication of the credit facilities provided for herein as well as activities as Administrative Agent. The Administrative Agent shall not be responsible for the negligence or misconduct of any sub-agents except to the extent that a court of competent jurisdiction determines in a final and non-appealable judgement that the Administrative Agent acted with gross negligence or willful misconduct in the selection of such sub-agents.

 

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Section 11.06    Resignation of Administrative Agent.

(a)    Subject to the appointment and acceptance of a successor Administrative Agent as provided in this Section 11.06, the Administrative Agent may resign at any time by notifying the Lenders, the Issuing Bank and the Borrower. Upon any such resignation, the Majority Lenders shall have the right, in consultation with the Borrower, to appoint a successor Administrative Agent. If no successor Administrative Agent shall have been so appointed by the Majority Lenders and shall have accepted such appointment within 30 days after the retiring Administrative Agent gives notice of its resignation as the retiring Administrative Agent (or such earlier day as shall be agreed by the Majority Lenders) (the “Resignation Effective Date”), then the retiring Administrative Agent may (but shall not be obligated to), on behalf of the Lenders and the Issuing Bank, appoint a successor Administrative Agent. Whether or not a successor has been appointed, such resignation shall become effective in accordance with such notice on the Resignation Effective Date. Upon the acceptance of its appointment as Administrative Agent hereunder by a successor Administrative Agent, such successor Administrative Agent shall succeed to, and become vested with, all the rights, powers, privileges and duties of the retiring Administrative Agent, and the retiring Administrative Agent shall be discharged from its duties and obligations hereunder. The fees payable by the Borrower to a successor Administrative Agent shall be the same as those payable to its predecessor unless otherwise agreed between the Borrower and such successor Administrative Agent. After the Administrative Agent’s resignation hereunder, the provisions of this Article XI and Section 12.03 shall continue in effect for the benefit of such retiring Administrative Agent, its sub-agents and their respective Related Parties in respect of any actions taken or omitted to be taken by any of them while it was acting as Administrative Agent.

(b)    With effect from the Resignation Effective Date (1) the retiring or removed Administrative Agent shall be discharged from its duties and obligations hereunder and under the other Loan Documents (except that in the case of any collateral security held by the Administrative Agent on behalf of the Lenders or the Issuing Bank under any of the Loan Documents, the retiring Administrative Agent shall continue to hold such collateral security until such time as a successor Administrative Agent is appointed) and (2) except for any indemnity payments or other amounts then owed to the retiring or removed Administrative Agent, all payments, communications and determinations provided to be made by, to or through the Administrative Agent shall instead be made by or to each Lender and the Issuing Bank directly, until such time, if any, as the Majority Lenders appoint a successor Administrative Agent as provided for above. Upon the acceptance of a successor’s appointment as Administrative Agent hereunder, such successor shall succeed to and become vested with all of the rights, powers, privileges and duties of the retiring (or removed) Administrative Agent (other than as provided in Section 5.03(e) and other than any rights to indemnity payments or other amounts owed to the retiring or removed Administrative Agent as of the Resignation Effective Date), and the retiring or removed Administrative Agent shall be discharged from all of its duties and obligations hereunder or under the other Loan Documents (if not already discharged therefrom as provided above in this Section 11.06). The fees payable by the Borrower to a successor Administrative Agent shall be the same as those payable to its predecessor unless otherwise agreed between the Borrower and such successor. After the retiring or removed Administrative Agent’s resignation or removal hereunder and under the other Loan Documents, the provisions of this Article XI and Section 12.03 shall continue in effect for the benefit of such retiring or removed Administrative Agent, its sub-agents and their respective Related Parties in respect of any actions taken or omitted to be taken by any of them (i) while the

 

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retiring or removed Administrative Agent was acting as Administrative Agent and (ii) after such resignation or removal for as long as any of them continues to act in any capacity hereunder or under the other Loan Documents, including (a) acting as collateral agent or otherwise holding any collateral security on behalf of any of the Lenders and (b) in respect of any actions taken in connection with transferring the agency to any successor Administrative Agent.

Section 11.07    Administrative Agent as Lender. The bank serving as the Administrative Agent hereunder shall have the same rights and powers in its capacity as a Lender as any other Lender and may exercise the same as though it were not the Administrative Agent, and such bank and its Affiliates may accept deposits from, lend money to and generally engage in any kind of business with the Borrower or any Subsidiary or other Affiliate thereof as if it were not the Administrative Agent hereunder.

Section 11.08    No Reliance. Each Lender and the Issuing Bank expressly acknowledges that none of the Administrative Agent nor the Arranger has made any representation or warranty to it, and that no act by the Administrative Agent or the Arranger hereafter taken, including any consent to, and acceptance of any assignment or review of the affairs of the Borrower, any other Loan Party or of any Affiliate thereof, shall be deemed to constitute any representation or warranty by the Administrative Agent or the Arranger to any Lender or the Issuing Bank as to any matter, including whether the Administrative Agent or the Arranger have disclosed material information in their (or their Related Parties’) possession. Each Lender and the Issuing Bank represents to the Administrative Agent and the Arranger that it has, independently and without reliance upon the Administrative Agent, the Arranger, any other Lender or any of their Related Parties and based on such documents and information as it has deemed appropriate, made its own credit analysis of, appraisal of, and investigation into, the business, prospects, operations, property, financial and other condition and creditworthiness of the Borrower, any other Loan Party and their Subsidiaries, and all applicable bank or other regulatory laws relating to the transactions contemplated hereby, and made its own decision to enter into this Agreement and to extend credit to the Borrower hereunder. Each Lender and the Issuing Bank also acknowledges that it will, independently and without reliance upon the Administrative Agent, the Arranger, any other Lender or any of their Related Parties and based on such documents and information as it shall from time to time deem appropriate, continue to make its own credit analysis, appraisals and decisions in taking or not taking action under or based upon this Agreement, any other Loan Document or any related agreement or any document furnished hereunder or thereunder, and to make such investigations as it deems necessary to inform itself as to the business, prospects, operations, property, financial and other condition and creditworthiness of the Borrower or any other Loan Party. Each Lender and the Issuing Bank represents and warrants that (i) the Loan Documents set forth the terms of a commercial lending facility and (ii) it is engaged in making, acquiring or holding commercial loans in the ordinary course and is entering into this Agreement as a Lender or Issuing Bank for the purpose of making, acquiring or holding commercial loans and providing other facilities set forth herein as may be applicable to such Lender or the Issuing Bank, and not for the purpose of purchasing, acquiring or holding any other type of financial instrument, and each Lender and the Issuing Bank agrees not to assert a claim in contravention of the foregoing. Each Lender and the Issuing Bank represents and warrants that it is sophisticated with respect to decisions to make, acquire and/or hold commercial loans and to provide other facilities set forth herein, as may be applicable to such Lender or the Issuing Bank, and either it, or the Person exercising discretion in making its decision to make, acquire and/or hold such commercial loans or to provide such other facilities, is experienced in making, acquiring or holding such commercial loans or providing such other facilities.

 

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Section 11.09    Administrative Agent May File Proofs of Claim. In case of the pendency of any receivership, insolvency, liquidation, bankruptcy, reorganization, arrangement, adjustment, composition or other judicial proceeding relative to the Borrower or any of its Subsidiaries, the Administrative Agent (irrespective of whether the principal of any Loan shall then be due and payable as herein expressed or by declaration or otherwise and irrespective of whether the Administrative Agent shall have made any demand on the Borrower) shall be entitled and empowered, by intervention in such proceeding or otherwise:

(a)    to file and prove a claim for the whole amount of the principal and interest owing and unpaid in respect of the Loans and all other Obligations that are owing and unpaid and to file such other documents as may be necessary or advisable in order to have the claims of the Lenders and the Administrative Agent (including any claim for the reasonable compensation, expenses, disbursements and advances of the Lenders and the Administrative Agent and their respective agents and counsel and all other amounts due the Lenders and the Administrative Agent under Section 12.03) allowed in such judicial proceeding; and

(b)    to collect and receive any monies or other property payable or deliverable on any such claims and to distribute the same;

and any custodian, receiver, assignee, trustee, liquidator, sequestrator or other similar official in any such judicial proceeding is hereby authorized by each Lender to make such payments to the Administrative Agent and, in the event that the Administrative Agent shall consent to the making of such payments directly to the Lenders, to pay to the Administrative Agent any amount due for the reasonable compensation, expenses, disbursements and advances of the Administrative Agent and its agents and counsel, and any other amounts due the Administrative Agent under Section 12.03.

Nothing contained herein shall be deemed to authorize the Administrative Agent to authorize or consent to or accept or adopt on behalf of any Lender any plan of reorganization, arrangement, adjustment or composition affecting the Obligations or the rights of any Lender or to authorize the Administrative Agent to vote in respect of the claim of any Lender in any such proceeding.

Section 11.10    Withholding Tax. To the extent required by any applicable law, the Administrative Agent may withhold from any payment to any Lender an amount equivalent to any applicable withholding Tax. Without limiting the provisions of Section 5.03(a) or Section 5.03(c), each Lender and the Issuing Bank shall, and does hereby, indemnify the Administrative Agent, and shall make payable in respect thereof within 30 days after demand therefor, against any and all Taxes and any and all related losses, claims, liabilities and expenses (including fees, charges and disbursements of any counsel for the Administrative Agent) incurred by or asserted against the Administrative Agent by the Internal Revenue Service or any other Governmental Authority as a result of the failure of the Administrative Agent to properly withhold Tax from amounts paid to or for the account of any Lender for any reason (including, without limitation, because the appropriate form was not delivered or not property executed, or because such Lender failed to notify the Administrative Agent of a change in circumstance that rendered the exemption from, or

 

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reduction of withholding tax ineffective). A certificate as to the amount of such payment or liability delivered to any Lender or the Issuing Bank by the Administrative Agent shall be conclusive absent manifest error. Each Lender and the Issuing Bank hereby authorizes the Administrative Agent to set off and apply any and all amounts at any time owing to such Lender or the Issuing Bank under this Agreement or any other Loan Document against any amount due the Administrative Agent under this Section 11.10. The agreements in this Section 11.10 shall survive the resignation and/or replacement of the Administrative Agent, any assignment of rights by, or the replacement of, a Lender, the termination of the Commitments and the repayment, satisfaction or discharge of all other Obligations.

Section 11.11    Authority of Administrative Agent to Release Collateral and Liens. Each Lender and the Issuing Bank, and by accepting the benefits of the Collateral, each Secured Swap Party and each Secured Cash Management Provider, hereby irrevocably authorizes the Administrative Agent to release (or evidence the release of) any Collateral that is permitted to be sold or released pursuant to the terms of the Loan Documents and to release (or evidence the release of) the GP Pledgor or any Guarantor from the Guarantee Agreement pursuant to the terms thereof. Each Lender and the Issuing Bank hereby authorizes the Administrative Agent to execute and deliver to the Borrower, at the Borrower’s sole cost and expense, any and all releases of Liens, termination statements, assignments or other documents reasonably requested by the Borrower in connection with any Disposition of Property to the extent such Disposition is permitted by the terms of Section 9.12 or is otherwise authorized by the terms of the Loan Documents.

Upon request by the Administrative Agent at any time, the Majority Lenders will confirm in writing the Administrative Agent’s authority to release or subordinate its interest in particular types or items of property, or to release the GP Pledgor or any Guarantor from its obligations under the Guarantee Agreement pursuant to this Section 11.11. The Administrative Agent shall not be responsible for or have a duty to ascertain or inquire into any representation or warranty regarding the existence, value or collectability of the Collateral, the existence, priority or perfection of the Administrative Agent’s Lien thereon, or any certificate prepared by Borrower or any Guarantor in connection therewith, nor shall the Administrative Agent be responsible or liable to the Lenders for any failure to monitor or maintain any portion of the Collateral.

Section 11.12    [Reserved].

Section 11.13    Credit Bidding. The Secured Parties hereby irrevocably authorize the Administrative Agent, at the direction of the Majority Lenders, to credit bid all or any portion of the Obligations (including by accepting some or all of the Collateral in satisfaction of some or all of the Obligations pursuant to a deed in lieu of foreclosure or otherwise) and in such manner purchase (either directly or through one or more acquisition vehicles) all or any portion of the Collateral (a) at any sale thereof conducted under the provisions of the Bankruptcy Code, including under Sections 363, 1123 or 1129 of the Bankruptcy Code, or any similar laws in any other jurisdictions to which the Borrower or any Guarantor is subject, or (b) at any other sale, foreclosure or acceptance of collateral in lieu of debt conducted by (or with the consent or at the direction of) the Administrative Agent (whether by judicial action or otherwise) in accordance with any applicable law. In connection with any such credit bid and purchase, the Obligations owed to the Secured Parties shall be entitled to be, and shall be, credit bid by the Administrative Agent at the direction of the Majority Lenders on a ratable basis (with Obligations with respect to contingent

 

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or unliquidated claims receiving contingent interests in the acquired assets on a ratable basis that shall vest upon the liquidation of such claims in an amount proportional to the liquidated portion of the contingent claim amount used in allocating the contingent interests) for the asset or assets so purchased (or for the equity interests or debt instruments of the acquisition vehicle or vehicles that are issued in connection with such purchase). In connection with any such bid, (i) the Administrative Agent shall be authorized to form one or more acquisition vehicles and to assign any successful credit bid to such acquisition vehicle or vehicles, (ii) each of the Secured Parties’ ratable interests in the Obligations which were credit bid shall be deemed without any further action under this Agreement to be assigned to such vehicle or vehicles for the purpose of closing such sale, (iii) the Administrative Agent shall be authorized to adopt documents providing for the governance of the acquisition vehicle or vehicles (provided that any actions by the Administrative Agent with respect to such acquisition vehicle or vehicles, including any Disposition of the assets or equity interests thereof, shall be governed, directly or indirectly, by, and the governing documents shall provide for, control by the vote of the Majority Lenders or their permitted assignees under the terms of this Agreement or the governing documents of the applicable acquisition vehicle or vehicles, as the case may be, irrespective of the termination of this Agreement and without giving effect to the limitations on actions by the Majority Lenders contained in Section 12.02 of this Agreement), (iv) the Administrative Agent on behalf of such acquisition vehicle or vehicles shall be authorized to issue to each of the Secured Parties, ratably on account of the relevant Obligations which were credit bid, interests, whether as equity, partnership interests, limited partnership interests or membership interests, in any such acquisition vehicle and/or debt instruments issued by such acquisition vehicle, all without the need for any Secured Party or acquisition vehicle to take any further action, and (v) to the extent that Obligations that are assigned to an acquisition vehicle are not used to acquire Collateral for any reason (as a result of another bid being higher or better, because the amount of Obligations assigned to the acquisition vehicle exceeds the amount of Obligations credit bid by the acquisition vehicle or otherwise), such Obligations shall automatically be reassigned to the Secured Parties pro rata with their original interest in such Obligations and the equity interests and/or debt instruments issued by any acquisition vehicle on account of such Obligations shall automatically be cancelled, without the need for any Secured Party or any acquisition vehicle to take any further action. Notwithstanding that the ratable portion of the Obligations of each Secured Party are deemed assigned to the acquisition vehicle or vehicles as set forth in clause (ii) above, each Secured Party shall execute such documents and provide such information regarding the Secured Party (and/or any designee of the Secured Party which will receive interests in or debt instruments issued by such acquisition vehicle) as the Administrative Agent may reasonably request in connection with the formation of any acquisition vehicle, the formulation or submission of any credit bid or the consummation of the transactions contemplated by such credit bid.

Section 11.14    Certain ERISA Matters.

(a)    Each Lender (x) represents and warrants, as of the date such Person became a Lender party hereto, to, and (y) covenants, from the date such Person became a Lender party hereto to the date such Person ceases being a Lender party hereto, for the benefit of the Administrative Agent and not, for the avoidance of doubt, to or for the benefit of the Borrower or any other Guarantor, that at least one of the following is and will be true:

(i)    such Lender is not using “plan assets” (within the meaning of Section 3(42) of ERISA or otherwise) of one or more Plans with respect to such Lender’s entrance into, participation in, administration of and performance of the Loans, the Letters of Credit, the Commitments or this Agreement,

 

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(ii)    the transaction exemption set forth in one or more PTEs, such as PTE 84-14 (a class exemption for certain transactions determined by independent qualified professional asset managers), PTE 95-60 (a class exemption for certain transactions involving insurance company general accounts), PTE 90-1 (a class exemption for certain transactions involving insurance company pooled separate accounts), PTE 91-38 (a class exemption for certain transactions involving bank collective investment funds) or PTE 96-23 (a class exemption for certain transactions determined by in-house asset managers), is applicable with respect to such Lender’s entrance into, participation in, administration of and performance of the Loans, the Letters of Credit, the Commitments and this Agreement,

(iii)    (A) such Lender is an investment fund managed by a “Qualified Professional Asset Manager” (within the meaning of Part VI of PTE 84-14), (B) such Qualified Professional Asset Manager made the investment decision on behalf of such Lender to enter into, participate in, administer and perform the Loans, the Letters of Credit, the Commitments and this Agreement, (C) the entrance into, participation in, administration of and performance of the Loans, the Letters of Credit, the Commitments and this Agreement satisfies the requirements of sub-sections (b) through (g) of Part I of PTE 84-14 and (D) to the best knowledge of such Lender, the requirements of subsection (a) of Part I of PTE 84-14 are satisfied with respect to such Lender’s entrance into, participation in, administration of and performance of the Loans, the Letters of Credit, the Commitments and this Agreement, or

(iv)    such other representation, warranty and covenant as may be agreed in writing between the Administrative Agent, in its sole discretion, and such Lender.

(b)    In addition, unless either (1) sub-clause (i) in the immediately preceding clause (a) is true with respect to a Lender or (2) a Lender has provided another representation, warranty and covenant in accordance with sub-clause (iv) in the immediately preceding clause (a), such Lender further (x) represents and warrants, as of the date such Person became a Lender party hereto, to, and (y) covenants, from the date such Person became a Lender party hereto to the date such Person ceases being a Lender party hereto, for the benefit of, the Administrative Agent and not, for the avoidance of doubt, to or for the benefit of the Borrower or any other Guarantor, that the Administrative Agent is not a fiduciary with respect to the assets of such Lender involved in such Lender’s entrance into, participation in, administration of and performance of the Loans, the Letters of Credit, the Commitments and this Agreement (including in connection with the reservation or exercise of any rights by the Administrative Agent under this Agreement, any Loan Document or any documents related hereto or thereto).

Section 11.15    Recovery of Erroneous Payments.

(a)    If the Administrative Agent notifies a Lender, Issuing Bank or any Person who has received funds on behalf of a Lender or Issuing Bank (any such Lender, Issuing Bank or other such recipient, a “Payment Recipient”) that the Administrative Agent has determined in its

 

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sole discretion (whether or not after receipt of any notice under immediately succeeding clause (b)) that any funds received by such Payment Recipient from the Administrative Agent or any of its Affiliates were erroneously transmitted to, or otherwise erroneously or mistakenly received by, such Payment Recipient (whether or not known to such Lender, Issuing Bank or other Payment Recipient on its behalf) (any such funds, whether received as a payment, prepayment or repayment of principal, interest, fees, distribution or otherwise, individually and collectively, an “Erroneous Payment”) and demands the return of such Erroneous Payment (or a portion thereof) (provided, that, without limiting any other rights or remedies (whether at law or in equity), the Administrative Agent may not make any such demand under this clause (a) with respect to an Erroneous Payment unless such demand is made on or prior to ten (10) Business Days of the date of receipt of such Erroneous Payment by the applicable Payment Recipient), such Erroneous Payment shall at all times remain the property of the Administrative Agent and shall be segregated by the Payment Recipient and held in trust for the benefit of the Administrative Agent, and such Lender or Issuing Bank shall (or, with respect to any Payment Recipient who received such funds on its behalf, shall cause such Payment Recipient to) promptly, but in no event later than two Business Days thereafter, return to the Administrative Agent the amount of any such Erroneous Payment (or portion thereof) as to which such a demand was made, in same day funds (in the currency so received), together with interest thereon in respect of each day from and including the date such Erroneous Payment (or portion thereof) was received by such Payment Recipient to the date such amount is repaid to the Administrative Agent in same day funds at the greater of the Federal Funds Rate and a rate determined by the Administrative Agent in accordance with banking industry rules on interbank compensation from time to time in effect. A notice of the Administrative Agent to any Payment Recipient under this clause (a) shall be conclusive, absent manifest error.

(b)    Without limiting the immediately preceding clause (a), each Lender or Issuing Bank, or any Person who has received funds on behalf of a Lender or Issuing Bank, hereby further agrees that if it receives a payment, prepayment or repayment (whether received as a payment, prepayment or repayment of principal, interest, fees, distribution or otherwise) from the Administrative Agent (or any of its Affiliates) (x) that is in a different amount than, or on a different date from, that specified in a notice of payment, prepayment or repayment sent by the Administrative Agent (or any of its Affiliates) with respect to such payment, prepayment or repayment, (y) that was not preceded or accompanied by a notice of payment, prepayment or repayment sent by the Administrative Agent (or any of its Affiliates), or (z) that such Lender or Issuing Bank, or other such recipient, otherwise becomes aware was transmitted, or received, in error or by mistake (in whole or in part) in each case:

(i)    (A) in the case of immediately preceding subclauses (x) or (y), an error shall be presumed to have been made (absent written confirmation from the Administrative Agent to the contrary) or (B) an error has been made (in the case of immediately preceding subclause (z)), in each case, with respect to such payment, prepayment or repayment; and

(ii)    such Lender or Issuing Bank shall (and shall cause any other recipient that receives funds on its respective behalf to) promptly (and, in all events, within one Business Day of its knowledge of such error) notify the Administrative Agent of its receipt of such payment, prepayment or repayment, the details thereof (in reasonable detail) and that it is so notifying the Administrative Agent pursuant to this Section 11.15(b).

 

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(c)    Each Lender or Issuing Bank hereby authorizes the Administrative Agent to set off, net and apply any and all amounts at any time owing to such Lender or Issuing Bank under any Loan Document, or otherwise payable or distributable by the Administrative Agent to such Lender or Issuing Bank from any source, against any amount due to the Administrative Agent under Section 11.15(a) or under the indemnification provisions of this Agreement.

(d)    In the event that an Erroneous Payment (or portion thereof) is not recovered by the Administrative Agent for any reason, after demand therefor by the Administrative Agent in accordance with Section 11.15(a), from any Lender or Issuing Bank that has received such Erroneous Payment (or portion thereof) (and/or from any Payment Recipient who received such Erroneous Payment (or portion thereof) on its respective behalf) (such unrecovered amount, an “Erroneous Payment Return Deficiency”), each party hereto agrees that, irrespective of whether the Administrative Agent may be equitably subrogated, the Administrative Agent shall be contractually subrogated to all the rights and interests of the applicable Lender or Issuing Bank under the Loan Documents with respect to each Erroneous Payment Return Deficiency (the “Erroneous Payment Subrogation Rights”).

(e)    The parties hereto agree that an Erroneous Payment shall not pay, prepay, repay, discharge or otherwise satisfy any Obligations owed by the Borrower, except, in each case, to the extent such Erroneous Payment is, and solely with respect to the amount of such Erroneous Payment that is, comprised of funds received by the Administrative Agent from the Borrower (or on behalf of the Borrower) for the purpose of paying, prepaying, repaying, discharging or otherwise satisfying any Obligations.

(f)    To the extent permitted by applicable law, no Payment Recipient shall assert any right or claim to an Erroneous Payment, and each Payment Recipient hereby waives, and is deemed to waive, any claim, counterclaim, defense or right of set-off or recoupment with respect to any demand, claim or counterclaim by the Administrative Agent for the return of any Erroneous Payment received, including without limitation waiver of any defense based on “discharge for value” or any similar doctrine.

(g)    Each party’s obligations, agreements and waivers under this Section 11.15 shall survive the resignation or replacement of the Administrative Agent, any transfer of rights or obligations by, or the replacement of, a Lender or Issuing Bank, the termination of the Commitments and/or the repayment, satisfaction or discharge of all Obligations (or any portion thereof) under any Loan Document.

(h)    For the avoidance of doubt, and notwithstanding anything in this Section 11.15 to the contrary, the existence of an Erroneous Payment as between the Administrative Agent and any Payment Recipient shall not affect the termination of this Agreement or the Commitments and/or the repayment, satisfaction or discharge of Obligations under any Loan Document to the extent that the Borrower (or another Person on behalf of the Borrower) has actually paid such amounts to such accounts and at such times, in each case as specified in a payoff letter executed by the Administrative Agent and the Borrower.

 

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ARTICLE XII

MISCELLANEOUS

Section 12.01    Notices.

(a)    Except in the case of notices and other communications expressly permitted to be given by telephone (and subject to Section 12.01(b)), all notices and other communications provided for herein shall be in writing and shall be delivered by hand or overnight courier service, mailed by certified or registered mail or sent by facsimile or electronic communication, as follows:

(i)      if to the Borrower, to it at:

1401 Lawrence Street

Suite 1750

Denver, Colorado 80202

Attention: Chief Financial Officer

Email: carrie.osicka@kimmeridge.com

(ii)     if to the Administrative Agent, to it at:

Bank of America, N.A.

Agency Management

Two Bryant Park, 7th Floor

Mail Code: NY1-540-07-10

New York, New York 10036-6712

Attention: Lisa Berishaj

Telephone: 646.556.2314

Fax: 704.683.9134

Email: lisa.berishaj@bofa.com

for payments and requests for credit extensions, continuations and conversions, to:

Bank of America, N.A.

900 W. Trade Street

Mail Code: NC1-026-06-09

Charlotte, NC 28255-0001

Attention: Ebony Porter

Telephone: 980.388.5085

Facsimile: 704.804.5420

Electronic Mail: eporter3@bofa.com

 

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(iii)    if to Bank of America, N.A. in its capacity as the Issuing Bank, to it at:

Bank of America, N.A.

Trade Operations

1 Fleet Way

Mail Code: PA6-580-02-30

Scranton, PA 18507

Telephone: 570.496.9619

Facsimile: 800.755.8740

Electronic Mail: tradeclientserviceteamus@baml.com

(iv)    if to any other Lender or the Issuing Bank, to it at its address (or facsimile number) set forth in its Administrative Questionnaire (including, as appropriate, notices delivered solely to the Person designated by a Lender on its Administrative Questionnaire then in effect for the delivery of notices that may contain material non-public information relating to the Borrower).

(v)    Notices and other communications sent by hand or overnight courier service, or mailed by certified or registered mail, shall be deemed to have been given when received; notices sent by facsimile shall be deemed to have been given when sent (except that, if not given during normal business hours for the recipient, shall be deemed to have been given at the opening of business on the next business day for the recipient). Notices and other communications delivered through Approved Electronic Platforms, to the extent provided in paragraph (b) below, shall be effective as provided in said paragraph (b).

(b)    Electronic Communications.

(i)    Notices and other communications to the Lenders and the Issuing Bank hereunder may be delivered or furnished by electronic communications (including e-mail, FpML messaging, and Internet or intranet websites) pursuant to procedures approved by the Administrative Agent; provided that the foregoing shall not apply to notices pursuant to Article II, Article III, Article IV and Article V unless otherwise agreed by the Administrative Agent, the Issuing Bank and the applicable Lender. The Administrative Agent, the Issuing Bank or the Borrower may, in its discretion, agree to accept notices and other communications to it hereunder by electronic communications pursuant to procedures approved by it; provided that approval of such procedures may be limited to particular notices or communications.

(ii)    Unless the Administrative Agent otherwise prescribes, (A) notices and other communications sent to an e-mail address shall be deemed received upon the sender’s receipt of an acknowledgement from the intended recipient (such as by the “return receipt requested” function, as available, return e-mail or other written acknowledgement), and (B) notices or communications posted to an Internet or intranet website shall be deemed received upon the deemed receipt by the intended recipient, at its e-mail address as described in the foregoing clause (A), of notification that such notice or communication is available and identifying the website address therefor; provided that, for both clauses (A) and (B) above, if such notice, email or other communication is not sent during the normal business hours of the recipient, such notice or communication shall be deemed to have been sent at the opening of business on the next business day for the recipient.

(c)    Change of Address, Etc. Any party hereto may change its address, facsimile number, telephone number or email address for notices and other communications hereunder by notice to the other parties hereto. All notices and other communications given to any party hereto

 

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in accordance with the provisions of this Agreement shall be deemed to have been given on the date of receipt. In addition, each Lender agrees to notify the Administrative Agent from time to time to ensure that the Administrative Agent has on record (i) an effective address, contact name, telephone number, facsimile number and electronic mail address to which notices and other communications may be sent and (ii) accurate wire instructions for such Lender.

(d)    Posting of Communications.

(i)    The Borrower agrees that the Administrative Agent may, but shall not be obligated to, make any Communications available to the Lenders and the Issuing Bank by posting the Communications on any Approved Electronic Platform.

(ii)    Although the Approved Electronic Platform and its primary web portal are secured with generally-applicable security procedures and policies implemented or modified by the Administrative Agent from time to time (including, as of the Effective Date, a user ID/password authorization system) and the Approved Electronic Platform is secured through a per-deal authorization method whereby each user may access the Approved Electronic Platform only on a deal-by-deal basis, each of the Lenders, the Issuing Bank and the Borrower acknowledges and agrees that the distribution of material through an electronic medium is not necessarily secure, that the Administrative Agent is not responsible for approving or vetting the representatives or contacts of any Lender that are added to the Approved Electronic Platform, and that there may be confidentiality and other risks associated with such distribution. Each of the Lenders, the Issuing Bank and the Borrower hereby approves distribution of the Communications through the Approved Electronic Platform and understands and assumes the risks of such distribution.

(iii)    THE APPROVED ELECTRONIC PLATFORM AND THE COMMUNICATIONS ARE PROVIDED “AS IS” AND “AS AVAILABLE”. THE APPLICABLE PARTIES DO NOT WARRANT THE ACCURACY OR COMPLETENESS OF THE COMMUNICATIONS, OR THE ADEQUACY OF THE APPROVED ELECTRONIC PLATFORM AND EXPRESSLY DISCLAIM LIABILITY FOR ERRORS OR OMISSIONS IN THE APPROVED ELECTRONIC PLATFORM AND THE COMMUNICATIONS. NO WARRANTY OF ANY KIND, EXPRESS, IMPLIED OR STATUTORY, INCLUDING ANY WARRANTY OF MERCHANTABILITY, FITNESS FOR A PARTICULAR PURPOSE, NON-INFRINGEMENT OF THIRD PARTY RIGHTS OR FREEDOM FROM VIRUSES OR OTHER CODE DEFECTS, IS MADE BY THE APPLICABLE PARTIES IN CONNECTION WITH THE COMMUNICATIONS OR THE APPROVED ELECTRONIC PLATFORM. IN NO EVENT SHALL THE ADMINISTRATIVE AGENT, ANY OTHER AGENT, ANY ARRANGER OR ANY OF THEIR RESPECTIVE RELATED PARTIES (COLLECTIVELY, “APPLICABLE PARTIES”) HAVE ANY LIABILITY TO ANY LOAN PARTY, ANY LENDER, THE ISSUING BANK OR ANY OTHER PERSON OR ENTITY FOR DAMAGES OF ANY KIND, INCLUDING DIRECT OR INDIRECT, SPECIAL, INCIDENTAL OR CONSEQUENTIAL DAMAGES, LOSSES, CLAIMS, LIABILITIES OR EXPENSES (WHETHER IN TORT, CONTRACT OR OTHERWISE) ARISING OUT OF THE TRANSMISSION OF COMMUNICATIONS THROUGH THE INTERNET OR THE APPROVED ELECTRONIC PLATFORM OF THE LOAN PARTIES, ANY LENDER, THE ISSUING BANK OR ANY OTHER PERSON OR ENTITY.

 

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(iv)    Each Lender and the Issuing Bank agrees that notice to it (as provided in the next sentence) specifying that Communications have been posted to the Approved Electronic Platform shall constitute effective delivery of the Communications to such Lender for purposes of the Loan Documents. Each Lender and Issuing Bank agrees (A) to notify the Administrative Agent in writing (which could be in the form of electronic communication) from time to time of such Lender’s or Issuing Bank’s (as applicable) email address to which the foregoing notice may be sent by electronic transmission and (B) that the foregoing notice may be sent to such email address.

(v)    Each of the Lenders, the Issuing Bank and the Borrower agrees that the Administrative Agent may, but (except as may be required by applicable law) shall not be obligated to, store the Communications on the Approved Electronic Platform in accordance with the Administrative Agent’s generally applicable document retention procedures and policies.

(vi)    Nothing herein shall prejudice the right of the Administrative Agent, any Lender or the Issuing Bank to give any notice or other communication pursuant to any Loan Document in any other manner specified in such Loan Document.

(e)    Reliance by Administrative Agent, Issuing Bank and Lenders. The Administrative Agent, the Issuing Bank and the Lenders shall be entitled to rely and act upon any notices (including telephonic notices and applications for Letters of Credit) purportedly given by or on behalf of the Borrower even if (i) such notices were not made in a manner specified herein, were incomplete or were not preceded or followed by any other form of notice specified herein, or (ii) the terms thereof, as understood by the recipient, varied from any confirmation thereof. The Borrower shall indemnify the Administrative Agent, the Issuing Bank, each Lender and the Related Parties of each of them from all losses, costs, expenses and liabilities resulting from the reliance by such Person on each notice purportedly given by or on behalf of the Borrower. All telephonic notices to and other telephonic communications with the Administrative Agent may be recorded by the Administrative Agent, and each of the parties hereto hereby consents to such recording.

Section 12.02    Waivers; Amendments.

(a)    No failure on the part of the Administrative Agent, the Issuing Bank or any Lender to exercise and no delay in exercising, and no course of dealing with respect to, any right, power or privilege, or any abandonment or discontinuance of steps to enforce such right, power or privilege, under any of the Loan Documents shall operate as a waiver thereof, nor shall any single or partial exercise of any right, power or privilege under any of the Loan Documents preclude any other or further exercise thereof or the exercise of any other right, power or privilege. The rights and remedies of the Administrative Agent, the Issuing Bank and the Lenders hereunder and under the other Loan Documents are cumulative and are not exclusive of any rights or remedies that they would otherwise have. No waiver of any provision of this Agreement or any other Loan Document or consent to any departure by the Borrower therefrom shall in any event be effective unless the same shall be permitted by Section 12.02(b), and then such waiver or consent shall be effective only in the specific instance and for the purpose for which given. Without limiting the generality of the foregoing, the making of a Loan or issuance of a Letter of Credit shall not be construed as a waiver of any Default, regardless of whether the Administrative Agent, any Lender or the Issuing Bank may have had notice or knowledge of such Default at the time.

 

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(b)    Subject to Section 3.03, neither this Agreement nor any provision hereof nor any Security Instrument nor any provision thereof may be waived, amended or modified except pursuant to an agreement or agreements in writing entered into by the Borrower and the Majority Lenders or by the Borrower and the Administrative Agent with the consent of the Majority Lenders; provided that no such agreement shall (i) increase the Commitment or the Maximum Credit Amount of any Lender without the written consent of such Lender, (ii) increase the Borrowing Base without the written consent of each non-Defaulting Lender (provided that no Lender’s Applicable Percentage of the Borrowing Base may be increased without such Lender’s written consent), decrease or maintain the Borrowing Base without the consent of the Required Lenders, or modify Section 2.07 in any manner that would increase the Borrowing Base without the consent of each Lender; provided that (A) a Scheduled Redetermination may be postponed by the Majority Lenders and (B) a reduction of the Borrowing Base pursuant to Section 2.07(f) may be waived or reduced with the consent of the Required Lenders, (iii) reduce the principal amount of any Loan or LC Disbursement or reduce the rate of interest thereon, or reduce any fees payable hereunder, or reduce any other Obligations hereunder or under any other Loan Document, without the written consent of each Lender affected thereby (other than default rate interest provided under Section 3.02(c)(ii) which may be amended, reduced or waived by the Majority Lenders), (iv) postpone the scheduled date of payment or prepayment of the principal amount of any Loan or LC Disbursement, or any interest thereon, or any fees payable hereunder, or any other Obligations hereunder or under any other Loan Document, or reduce the amount of, waive or excuse any such payment, or postpone or extend the Termination Date without the written consent of each Lender affected thereby (other than mandatory prepayments required by Section 3.04(c)(ii) or Section 3.04(c)(iii) which may be reduced or waived by the Required Lenders), (v) change Section 4.01(b) or Section 4.01(c) in a manner that would alter the pro rata sharing of payments required thereby, without the written consent of each Lender, (vi) waive or amend Section 3.04(c)(i), Section 6.01, Section 8.14, Section 10.02(c) or Section 12.14 or change the definition of the terms “Domestic Subsidiary”, “Foreign Subsidiary” or “Subsidiary”, without the written consent of each Lender; provided, further, that any waiver or amendment to the terms of Section 12.14, this proviso in this Section 12.02(b)(vi) or Section 12.02(b)(vii) shall also require the written consent of each Secured Swap Party and each Secured Cash Management Provider, and any amendment or waiver to the terms of Section 10.02(c) shall also require the written consent of each Secured Swap Party or Secured Cash Management Provider adversely affected thereby, (vii) amend or otherwise modify any Security Instrument in a manner that results in the Secured Swap Obligations or Secured Cash Management Obligations secured by such Security Instrument no longer being secured thereby on an equal and ratable basis with the principal of the Loans, or amend or otherwise change the definition of “Secured Swap Agreement,” “Secured Swap Obligations” or “Secured Swap Party”, without the written consent of each Secured Swap Party adversely affected thereby, or the definition of “Secured Cash Management Agreement,” “Secured Cash Management Obligations” or “Secured Cash Management Provider,” without the written consent of each Secured Cash Management Provider adversely affected thereby, (viii) release the GP Pledgor or any Guarantor (except , in each case, as set forth in this Agreement or in the Guarantee Agreement) or release all or substantially all of the Collateral (other than as provided in Section 11.11), or reduce the percentage set forth in Section 8.13(a) to less than 85%, without the written consent of each Lender, (ix) change any of the provisions of this Section 12.02(b) or the definitions of

 

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Required Lenders” or “Majority Lenders” or any other provision hereof specifying the number or percentage of Lenders required to waive, amend or modify any rights hereunder or under any other Loan Documents or make any determination or grant any consent hereunder or any other Loan Documents, without the written consent of each Lender, (x) subordinate, or have the effect of subordinating, the Obligations hereunder to any other Debt or other obligation (other than as expressly permitted hereunder) without the written consent of each Lender or (xi) subordinate, or have the effect of subordinating, the Liens securing the Obligations to Liens securing any other Debt or other obligation (other than as expressly permitted hereunder) without the written consent of each Lender; provided further that no such agreement shall amend, modify or otherwise affect the rights or duties of the Administrative Agent or the Issuing Bank hereunder or under any other Loan Document without the prior written consent of the Administrative Agent or the Issuing Bank, as the case may be. Notwithstanding the foregoing, (A) any supplement to Schedule 7.14 (Subsidiaries), Schedule 7.18 (Gas Imbalances; Other Prepayments), Schedule 7.19 (Marketing Agreements) and Schedule 7.20 (Swap Agreements) shall, in each case, be effective simply by delivering to the Administrative Agent a supplemental schedule clearly marked as such and, upon receipt, the Administrative Agent will promptly deliver a copy thereof to the Lenders, (B) any Security Instrument may be supplemented to add additional collateral or join additional Persons as Guarantors with the consent of the Administrative Agent, (C) the Borrower and the Administrative Agent may amend this Agreement or any other Loan Document without the consent of the Lenders in order to correct, amend or cure any ambiguity, inconsistency or defect or correct any typographical error or other manifest error in any Loan Document and (D) the Administrative Agent (or other applicable Credit Party) and the Borrower may enter into any amendment, modification or waiver of this Agreement or any other Loan Document or enter into any agreement or instrument to effect the granting, perfection, protection, expansion or enhancement of any security interest in any Mortgaged Property or Property that becomes Mortgaged Property to secure the Obligations for the benefit of the Lenders or as required by any Governmental Requirement to give effect to, protect or otherwise enhance the rights or benefits of any Lender under the Loan Documents without the consent of any Lender.

Section 12.03    Expenses, Indemnity; Damage Waiver.

(a)    The Borrower shall pay (i) all reasonable and documented out-of-pocket expenses incurred by the Administrative Agent and its Affiliates (limited, in the case of legal expenses, to the reasonable and documented out-of-pocket fees, charges and disbursements of one firm of primary legal counsel and one firm of local counsel in each appropriate jurisdiction (which may include a single special counsel acting in multiple jurisdictions)), and including, without limitation, other reasonable and documented expenses for outside consultants for the Administrative Agent, the reasonable travel, photocopy, mailing, courier, telephone and other similar expenses, and the cost of environmental non-invasive assessments and audits and surveys and appraisals, in connection with the syndication of the credit facilities provided for herein, the preparation, negotiation, execution, delivery and administration (both before and after the execution hereof and including advice of counsel to the Administrative Agent as to the rights and duties of the Administrative Agent and the Lenders with respect thereto) of this Agreement and the other Loan Documents and any amendments, modifications or waivers of or consents related to the provisions hereof or thereof (whether or not the transactions contemplated hereby or thereby shall be consummated), (ii) all reasonable and documented costs, expenses, Taxes, assessments and other charges incurred by the Administrative Agent or any Lender in connection with any

 

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filing, registration, recording or perfection of any security interest contemplated by this Agreement or any Security Instrument or any other document referred to therein, (iii) all reasonable and documented out-of-pocket expenses incurred by the Issuing Bank in connection with the issuance, amendment, renewal, reinstatement or extension of any Letter of Credit or any demand for payment thereunder, (iv) all reasonable and documented out-of-pocket expenses incurred by the Administrative Agent, the Issuing Bank or any Lender (limited, in the case of legal expenses, to the reasonable and documented fees, charges and disbursements of one firm of primary legal counsel and one firm of local counsel in each appropriate jurisdiction (which may include a single special counsel acting in multiple jurisdictions) for the Administrative Agent, the Issuing Bank and the Lenders (and in the case of an actual or perceived conflict of interest, of another firm of counsel for such affected parties)), in connection with the enforcement or protection of its rights in connection with this Agreement or any other Loan Document, including its rights under this Section 12.03, or in connection with the Loans made or Letters of Credit issued hereunder, including, without limitation, all such out-of-pocket expenses incurred during any workout, restructuring or negotiations in respect of such Loans or Letters of Credit

(b)    THE BORROWER SHALL INDEMNIFY THE ADMINISTRATIVE AGENT, THE ARRANGER, THE ISSUING BANK AND EACH LENDER, AND EACH RELATED PARTY OF ANY OF THE FOREGOING PERSONS (EACH SUCH PERSON BEING CALLED AN “INDEMNITEE”) AGAINST, AND DEFEND AND HOLD EACH INDEMNITEE HARMLESS FROM, ANY AND ALL LOSSES, CLAIMS, DAMAGES, PENALTIES, LIABILITIES AND RELATED REASONABLE AND DOCUMENTED EXPENSES (LIMITED, IN THE CASE OF LEGAL EXPENSES, TO THE FEES, CHARGES AND DISBURSEMENTS OF ONE FIRM OF PRIMARY LEGAL COUNSEL AND ONE FIRM OF LOCAL COUNSEL IN EACH APPROPRIATE JURISDICTION FOR ALL INDEMNITEES (AND, IN THE CASE OF AN ACTUAL OR PERCEIVED CONFLICT OF INTEREST, OF ANOTHER FIRM OF COUNSEL FOR SUCH AFFECTED INDEMNITEES)), INCURRED BY OR ASSERTED AGAINST ANY INDEMNITEE ARISING OUT OF, IN CONNECTION WITH, OR AS A RESULT OF (i) THE EXECUTION OR DELIVERY OF THIS AGREEMENT OR ANY OTHER LOAN DOCUMENT OR ANY AGREEMENT OR INSTRUMENT CONTEMPLATED HEREBY OR THEREBY, THE PERFORMANCE BY THE PARTIES HERETO OR THE PARTIES TO ANY OTHER LOAN DOCUMENT OF THEIR RESPECTIVE OBLIGATIONS HEREUNDER OR THEREUNDER OR THE CONSUMMATION OF THE TRANSACTIONS CONTEMPLATED HEREBY OR BY ANY OTHER LOAN DOCUMENT, (ii) THE FAILURE OF THE BORROWER OR ANY OTHER LOAN PARTY TO COMPLY WITH THE TERMS OF ANY LOAN DOCUMENT, INCLUDING THIS AGREEMENT, OR WITH ANY GOVERNMENTAL REQUIREMENT, (iii) ANY INACCURACY OF ANY REPRESENTATION OR ANY BREACH OF ANY WARRANTY OR COVENANT OF THE BORROWER OR ANY GUARANTOR SET FORTH IN ANY OF THE LOAN DOCUMENTS OR ANY INSTRUMENTS, DOCUMENTS OR CERTIFICATIONS DELIVERED IN CONNECTION THEREWITH, (iv) ANY LOAN OR LETTER OF CREDIT OR THE USE OF THE PROCEEDS THEREFROM, INCLUDING, WITHOUT LIMITATION, (A) ANY REFUSAL BY THE ISSUING BANK TO HONOR A DEMAND FOR PAYMENT UNDER A LETTER OF CREDIT IF THE DOCUMENTS PRESENTED IN CONNECTION WITH SUCH DEMAND DO NOT STRICTLY COMPLY WITH THE TERMS OF SUCH LETTER OF CREDIT, OR (B) THE PAYMENT OF A DRAWING UNDER ANY LETTER OF CREDIT NOTWITHSTANDING THE NON-COMPLIANCE, NON-DELIVERY OR OTHER

 

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IMPROPER PRESENTATION OF THE DOCUMENTS PRESENTED IN CONNECTION THEREWITH, (v) ANY OTHER ASPECT OF THE LOAN DOCUMENTS, (vi) THE OPERATIONS OF THE BUSINESS OF THE LOAN PARTIES BY THE LOAN PARTIES, (vii) ANY ASSERTION THAT THE LENDERS WERE NOT ENTITLED TO RECEIVE THE PROCEEDS RECEIVED PURSUANT TO THE SECURITY INSTRUMENTS, (viii) ANY ENVIRONMENTAL LAW APPLICABLE TO THE BORROWER OR ANY SUBSIDIARY OR ANY OF THEIR PROPERTIES OR OPERATIONS, INCLUDING THE PRESENCE, GENERATION, STORAGE, RELEASE, THREATENED RELEASE, USE, TRANSPORT, DISPOSAL, ARRANGEMENT OF DISPOSAL OR TREATMENT OF HAZARDOUS MATERIALS ON OR AT ANY OF THEIR PROPERTIES, (ix) THE BREACH OR NON-COMPLIANCE BY THE BORROWER OR ANY SUBSIDIARY WITH ANY ENVIRONMENTAL LAW APPLICABLE TO THE BORROWER OR ANY SUBSIDIARY, (x) THE PAST OWNERSHIP BY THE BORROWER OR ANY SUBSIDIARY OF ANY OF THEIR PROPERTIES OR PAST ACTIVITY ON ANY OF THEIR PROPERTIES WHICH, THOUGH LAWFUL AND FULLY PERMISSIBLE AT THE TIME, COULD RESULT IN PRESENT LIABILITY, (xi) THE PRESENCE, USE, RELEASE, STORAGE, TREATMENT, DISPOSAL, GENERATION, THREATENED RELEASE, TRANSPORT, ARRANGEMENT FOR TRANSPORT OR ARRANGEMENT FOR DISPOSAL OF HAZARDOUS MATERIALS ON OR AT ANY OF THE PROPERTIES OWNED OR OPERATED BY THE BORROWER OR ANY SUBSIDIARY OR ANY ACTUAL OR ALLEGED PRESENCE OR RELEASE OF HAZARDOUS MATERIALS ON OR FROM ANY PROPERTY OWNED OR OPERATED BY ANY LOAN PARTY, (xii) ANY ENVIRONMENTAL LIABILITY RELATED IN ANY WAY TO THE BORROWER OR ANY OF ITS SUBSIDIARIES, OR (xiii) ANY OTHER ENVIRONMENTAL, HEALTH OR SAFETY CONDITION IN CONNECTION WITH THE LOAN DOCUMENTS, OR (xiv) ANY ACTUAL OR PROSPECTIVE CLAIM, LITIGATION, INVESTIGATION OR PROCEEDING RELATING TO ANY OF THE FOREGOING, WHETHER BASED ON CONTRACT, TORT OR ANY OTHER THEORY AND REGARDLESS OF WHETHER ANY INDEMNITEE IS A PARTY THERETO, AND SUCH INDEMNITY SHALL EXTEND TO EACH INDEMNITEE NOTWITHSTANDING THE SOLE OR CONCURRENT NEGLIGENCE OF EVERY KIND OR CHARACTER WHATSOEVER, WHETHER ACTIVE OR PASSIVE, WHETHER AN AFFIRMATIVE ACT OR AN OMISSION, INCLUDING WITHOUT LIMITATION, ALL TYPES OF NEGLIGENT CONDUCT IDENTIFIED IN THE RESTATEMENT (SECOND) OF TORTS OF ONE OR MORE OF THE INDEMNITEES OR BY REASON OF STRICT LIABILITY IMPOSED WITHOUT FAULT ON ANY ONE OR MORE OF THE INDEMNITEES; PROVIDED THAT SUCH INDEMNITY SHALL NOT, AS TO ANY INDEMNITEE, BE AVAILABLE TO THE EXTENT THAT SUCH LOSSES, CLAIMS, DAMAGES, LIABILITIES OR RELATED EXPENSES ARE DETERMINED BY A COURT OF COMPETENT JURISDICTION BY FINAL AND NONAPPEALABLE JUDGMENT TO HAVE RESULTED FROM (A) THE GROSS NEGLIGENCE, BAD FAITH OR WILLFUL MISCONDUCT OF SUCH INDEMNITEE, (B) A MATERIAL BREACH IN BAD FAITH OF SUCH INDEMNITEE’S FUNDING OBLIGATIONS UNDER THIS AGREEMENT OR (C) A DISPUTE SOLELY BETWEEN OR AMONG INDEMNITEES AND NOT INVOLVING ANY ACT OR OMISSION OF THE BORROWER OR ANY OF ITS SUBSIDIARIES OR ANY OF THEIR RESPECTIVE AFFILIATES (OTHER THAN ANY CLAIMS AGAINST AN INDEMNITEE IN ITS CAPACITY OR FULFILLING ITS ROLE AS THE ADMINISTRATIVE AGENT, AN AGENT

 

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OR ARRANGER WITH RESPECT TO THIS AGREEMENT). THIS SECTION 12.03(B) SHALL NOT APPLY WITH RESPECT TO TAXES OTHER THAN ANY TAXES THAT REPRESENT LOSSES, CLAIMS, DAMAGES, PENALTIES, LIABILITIES AND RELATED REASONABLE AND DOCUMENTED EXPENSES FROM ANY NON-TAX CLAIM.

(c)    To the extent that the Borrower for any reason fails to indefeasibly pay any amount required to be paid by it to the Administrative Agent, the Arranger or the Issuing Bank, or any of the Related Parties of any of the foregoing Persons, under Section 12.03(a) or Section 12.03(b), each Lender severally agrees to pay to the Administrative Agent, the Arranger or the Issuing Bank, or such Related Party, as the case may be, such Lender’s Applicable Percentage (as in effect on the date reimbursement or indemnification is sought under this Section 12.03) of such unpaid amount; provided that the unreimbursed expense or indemnified loss, claim, damage, liability or related expense, as the case may be, was incurred by or asserted against the Administrative Agent, the Arranger or the Issuing Bank in its capacity as such or against any Related Party of any of the foregoing acting for the Administrative Agent (or any such sub-agent) or the Issuing Bank with such capacity. The obligations of the Lenders under this clause (c) are subject to the provisions of Section 2.02(e).

(d)    To the extent permitted by applicable law (i) the Borrower shall not assert, and the Borrower hereby waives, any claim against any Indemnitee for any damages arising from the use by others of information or other materials obtained through telecommunications, electronic or other information transmission systems (including the Internet), and no Indemnitee referred to in clause (b) above shall be liable for any damages arising from the use by unintended recipients of any information or other materials distributed to such unintended recipients by such Indemnitee through telecommunications, electronic or other information transmission systems in connection with this Agreement or the other Loan Documents or the transactions contemplated hereby and thereby, and (ii) no party hereto shall assert, and each such party hereby waives, any claim against any other party hereto, on any theory of liability, for special, indirect, consequential or punitive damages (as opposed to direct or actual damages) arising out of, in connection with, or as a result of, this Agreement, any other Loan Document, or any agreement or instrument contemplated hereby or thereby, the Transactions, any Loan or Letter of Credit or the use of the proceeds thereof; provided that, nothing in this clause (d)(ii) shall relieve the Borrower of any obligation it may have to indemnify an Indemnitee against special, indirect, consequential or punitive damages asserted against such Indemnitee by a third party.

(e)    All amounts due under this Section 12.03 shall be payable not later than ten days after written demand therefor.

Section 12.04    Successors and Assigns.

(a)    The provisions of this Agreement shall be binding upon and inure to the benefit of the parties hereto and their respective successors and assigns permitted hereby (including any Affiliate of the Issuing Bank that issues any Letter of Credit), except that (i) the Borrower may not assign or otherwise transfer any of its rights or obligations hereunder without the prior written consent of each Lender (and any attempted assignment or transfer by the Borrower without such consent shall be null and void), and (ii) no Lender may assign or otherwise transfer its rights or obligations hereunder except in accordance with this Section 12.04. Nothing in this Agreement,

 

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expressed or implied, shall be construed to confer upon any Person (other than the parties hereto, their respective successors and assigns permitted hereby (including any Affiliate of the Issuing Bank that issues any Letter of Credit), Participants (to the extent provided in Section 12.04(c)) and, to the extent expressly contemplated hereby, the Related Parties of each of the Administrative Agent, the Issuing Bank and the Lenders) any legal or equitable right, remedy or claim under or by reason of this Agreement.

(b)    (i) Subject to the conditions set forth in Section 12.04(b)(ii), any Lender may assign to one or more Persons (other than an Ineligible Institution) all or a portion of its rights and obligations under this Agreement (including all or a portion of its Commitment, participations in Letters of Credit and the Loans at the time owing to it) with the prior written consent (such consent not to be unreasonably withheld or delayed) of:

(A)    the Borrower; provided that no consent of the Borrower shall be required if such assignment is to a Lender, an Affiliate of a Lender, an Approved Fund or, if an Event of Default has occurred and is continuing, to any other assignee; provided, further that the Borrower shall be deemed to have consented to any such assignment unless it shall object thereto by written notice to the Administrative Agent within five (5) Business Days after having received notice thereof;

(B)    the Administrative Agent; provided that no consent of the Administrative Agent shall be required for an assignment to an assignee that is a Lender immediately prior to giving effect to such assignment; and

(C)    the Issuing Bank (such consent not to be unreasonably withheld, conditioned or delayed) provided that no consent of the Issuing Bank shall be required for an assignment to an assignee that is a Lender immediately prior to giving effect to such assignment.

(ii)    Assignments shall be subject to the following additional conditions:

(A)    except in the case of an assignment to a Lender or an Affiliate of a Lender or an Approved Fund or an assignment of the entire remaining amount of the assigning Lender’s Commitment or Loans, the amount of the Commitment or Loans of the assigning Lender subject to each such assignment (determined as of the date the Assignment and Assumption with respect to such assignment is delivered to the Administrative Agent) shall not be less than $5,000,000 unless each of the Borrower and the Administrative Agent otherwise consent; provided that no such consent of the Borrower shall be required if an Event of Default has occurred and is continuing;

(B)    each partial assignment shall be made as an assignment of a proportionate part of all the assigning Lender’s rights and obligations under this Agreement;

(C)    the parties to each assignment shall execute and deliver to the Administrative Agent (x) an Assignment and Assumption or (y) to the extent applicable, an agreement incorporating an Assignment and Assumption by reference pursuant to an Approved Electronic Platform as to which the Administrative Agent and the parties to the Assignment and Assumption are participants, together with a processing and recordation fee of $3,500 (unless waived by the Administrative Agent); and

 

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(D)    the assignee, if it shall not be a Lender, shall deliver to the Administrative Agent an Administrative Questionnaire in which the assignee designates one or more credit contacts to whom all syndicate-level information (which may contain material non-public information about the Borrower and the Guarantors and their related parties or their respective securities) will be made available and who may receive such information in accordance with the assignee’s compliance procedures and applicable laws, including Federal and state securities laws.

(iii)    Subject to the acceptance and recording thereof pursuant to Section 12.04(b)(iv), from and after the effective date specified in each Assignment and Assumption the assignee thereunder shall be a party hereto and, to the extent of the interest assigned by such Assignment and Assumption, have the rights and obligations of a Lender under this Agreement, and the assigning Lender thereunder shall, to the extent of the interest assigned by such Assignment and Assumption, be released from its obligations under this Agreement (and, in the case of an Assignment and Assumption covering all of the assigning Lender’s rights and obligations under this Agreement, such Lender shall cease to be a party hereto but shall continue to be entitled to the benefits of Section 5.01, Section 5.02, Section 5.03 and Section 12.03). Any assignment or transfer by a Lender of rights or obligations under this Agreement that does not comply with this Section 12.04(b) shall be treated for purposes of this Agreement as a sale by such Lender of a participation in such rights and obligations in accordance with Section 12.04(c).

(iv)    The Administrative Agent, acting for this purpose as a non-fiduciary agent of the Borrower, shall maintain at one of its offices a copy of each Assignment and Assumption delivered to it and a register for the recordation of the names and addresses of the Lenders, and the Maximum Credit Amount of, and principal amount (and stated interest) of the Loans and LC Disbursements owing to, each Lender pursuant to the terms hereof from time to time (the “Register”). The entries in the Register shall be conclusive (absent manifest error), and the Borrower, the Administrative Agent, the Issuing Bank and the Lenders may treat each Person whose name is recorded in the Register pursuant to the terms hereof as a Lender hereunder for all purposes of this Agreement, notwithstanding notice to the contrary. The Register shall be available for inspection by the Borrower, the Issuing Bank and any Lender, at any reasonable time and from time to time upon reasonable prior notice. In connection with any changes to the Register, if necessary, the Administrative Agent will reflect the revisions on Annex I and forward a copy of such revised Annex I to the Borrower, the Issuing Bank and each Lender.

(v)    Upon its receipt of (x) a duly completed Assignment and Assumption executed by an assigning Lender and an assignee or (y) to the extent applicable, an agreement incorporating an Assignment and Assumption by reference pursuant to an Approved Electronic Platform as to which the Administrative Agent and the parties to the Assignment and Assumption are participants, the assignee’s completed Administrative Questionnaire (unless the assignee shall already be a Lender hereunder), the processing and recordation fee referred to in Section 12.04(b) and any written consent to such assignment required by Section 12.04(b), the Administrative Agent shall accept such Assignment and Assumption and record the information contained therein in the Register; provided that if either the assigning Lender or the assignee shall

 

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have failed to make any payment required to be made by it pursuant to Section 2.08(d), Section 2.08(e), Section 2.05(b), Section 4.02, Section 12.03(c) or Section 12.04(e) below, the Administrative Agent shall have no obligation to accept such Assignment and Assumption and record the information therein in the Register unless and until such payment shall have been made in full, together with all accrued interest thereon. No assignment shall be effective for purposes of this Agreement unless it has been recorded in the Register as provided in this Section 12.04(b).

(c)    Any Lender may, without the consent of, or notice to, the Borrower, the Administrative Agent or the Issuing Bank, sell participations to one or more banks or other entities (a “Participant”), other than an Ineligible Institution, in all or a portion of such Lender’s rights and/or obligations under this Agreement (including all or a portion of its Commitment and/or the Loans owing to it); provided that (A) such Lender’s obligations under this Agreement shall remain unchanged, (B) such Lender shall remain solely responsible to the other parties hereto for the performance of such obligations and (C) the Borrower, the Administrative Agent, the Issuing Bank and the other Lenders shall continue to deal solely and directly with such Lender in connection with such Lender’s rights and obligations under this Agreement. Any agreement or instrument pursuant to which a Lender sells such a participation shall provide that such Lender shall retain the sole right to enforce this Agreement and to approve any amendment, modification or waiver of any provision of this Agreement; provided that such agreement or instrument may provide that such Lender will not, without the consent of the Participant, agree to any amendment, modification or waiver described in the proviso to Section 12.02(b) that affects such Participant. The Borrower agrees that each Participant shall be entitled to the benefits of Section 5.01, Section 5.02 and Section 5.03 (subject to the requirements and limitations therein, including the requirements under Section 5.03(e) (it being understood that the documentation required under Section 5.03(e) shall be delivered to the participating Lender and the information)) to the same extent as if it were a Lender and had acquired its interest by assignment pursuant to Section 12.04(b); provided that such Participant (A) agrees to be subject to the provisions of Section 5.04 as if it were an assignee under Section 12.04(b) and (B) shall not be entitled to receive any greater payment under Section 5.01 or Section 5.03, with respect to any participation, than its participating Lender would have been entitled to receive, except to the extent such entitlement to receive a greater payment results from a Change in Law that occurs after the Participant acquired the applicable participation. Each Lender that sells a participation agrees, at the Borrower’s request and expense, to use reasonable efforts to cooperate with the Borrower to effectuate the provisions of Section 5.04(b) with respect to any Participant. To the extent permitted by law, each Participant also shall be entitled to the benefits of Section 12.08 as though it were a Lender; provided that such Participant agrees to be subject to Section 4.01(c) as though it were a Lender. Each Lender that sells a participation shall, acting solely for this purpose as a non-fiduciary agent of the Borrower, maintain a register on which it enters the name and address of each Participant and the principal amounts (and stated interest) of each Participant’s interest in the Loans or other obligations under the Loan Documents (the “Participant Register”); provided that no Lender shall have any obligation to disclose all or any portion of the Participant Register (including the identity of any Participant or any information relating to a Participant’s interest in any Commitments, Loans, Letters of Credit or its other obligations under any Loan Document) to any Person except to the extent that such disclosure is necessary to establish that such Commitment, Loan, Letter of Credit or other obligation is in registered form under Section 5f.103-1(c) of the United States Treasury Regulations and Section 1.163-5(b) of the Proposed United States Treasury Regulations. The entries in the Participant Register shall be conclusive absent manifest error, and such Lender shall treat each Person whose

 

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name is recorded in the Participant Register as the owner of such participation for all purposes of this Agreement notwithstanding any notice to the contrary. For the avoidance of doubt, the Administrative Agent (in its capacity as Administrative Agent) shall have no responsibility for maintaining a Participant Register.

(d)    Any Lender may at any time pledge or assign a security interest in all or any portion of its rights under this Agreement to secure obligations of such Lender, including any pledge or assignment to secure obligations to a Federal Reserve Bank or any central bank having jurisdiction over such Lender, and this Section 12.04(d) shall not apply to any such pledge or assignment of a security interest; provided that no such pledge or assignment of a security interest shall release a Lender from any of its obligations hereunder or substitute any such pledgee or assignee for such Lender as a party hereto.

(e)    Certain Additional Payments. In connection with any assignment of rights and obligations of any Defaulting Lender hereunder, no such assignment shall be effective unless and until, in addition to the other conditions thereto set forth herein, the parties to the assignment shall make such additional payments to the Administrative Agent in an aggregate amount sufficient, upon distribution thereof as appropriate (which may be outright payment, purchases by the assignee of participations or subparticipations, or other compensating actions, including funding, with the consent of the Borrower and the Administrative Agent, the applicable pro rata share of Loans previously requested but not funded by the Defaulting Lender, to each of which the applicable assignee and assignor hereby irrevocably consent), to (x) pay and satisfy in full all payment liabilities then owed by such Defaulting Lender to the Administrative Agent, the Issuing Bank or any Lender hereunder (and interest accrued thereon) and (y) acquire (and fund as appropriate) its full pro rata share of all Loans and participations in Letters of Credit in accordance with its Applicable Percentage. Notwithstanding the foregoing, in the event that any assignment of rights and obligations of any Defaulting Lender hereunder shall become effective under applicable law without compliance with the provisions of this clause (e), then the assignee of such interest shall be deemed to be a Defaulting Lender for all purposes of this Agreement until such compliance occurs.

Section 12.05    Survival; Revival; Reinstatement.

(a)    All covenants, agreements, representations and warranties made by the Borrower herein and in the certificates or other instruments delivered in connection with or pursuant to this Agreement and in the other Loan Documents or any other Loan Document shall be considered to have been relied upon by the other parties hereto and shall survive the execution and delivery of this Agreement and the making of any Loans and issuance of any Letters of Credit, regardless of any investigation made by any such other party or on its behalf and notwithstanding that the Administrative Agent, the Issuing Bank or any Lender may have had notice or knowledge of any Default or incorrect representation or warranty at the time any credit is extended hereunder, and shall continue in full force and effect until Payment in Full. The provisions of Section 5.01, Section 5.02, Section 5.03, Section 12.03 and Article XI shall survive and remain in full force and effect regardless of the consummation of the transactions contemplated hereby, the repayment of the Loans, the expiration or termination of the Letters of Credit and the Commitments or the termination of this Agreement, any other Loan Document or any provision hereof or thereof.

 

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(b)    To the extent that any payments on the Obligations or proceeds of any Collateral are subsequently invalidated, declared to be fraudulent or preferential, set aside or required to be repaid to a trustee, debtor in possession, receiver or other Person under any bankruptcy law, common law or equitable cause, then to such extent, the Obligations so satisfied shall be revived and continue as if such payment or proceeds had not been received and the Administrative Agent’s and the Lenders’ Liens, security interests, rights, powers and remedies under this Agreement and each Loan Document shall continue in full force and effect. In such event, each Loan Document shall be automatically reinstated and the Borrower shall take such action as may be reasonably requested by the Administrative Agent and the Lenders to effect such reinstatement.

Section 12.06    Integration; ENTIRE AGREEMENT; Effectiveness.

(a)    This Agreement, the other Loan Documents and any separate letter agreements with respect to fees payable to the Issuing Bank constitute the entire contract among the parties relating to the subject matter hereof and thereof and supersede any and all previous agreements and understandings, oral or written, relating to the subject matter hereof and thereof. THIS AGREEMENT AND THE OTHER LOAN DOCUMENTS REPRESENT THE FINAL AGREEMENT AMONG THE PARTIES HERETO AND THERETO AND MAY NOT BE CONTRADICTED BY EVIDENCE OF PRIOR, CONTEMPORANEOUS OR SUBSEQUENT ORAL AGREEMENTS OF THE PARTIES. THERE ARE NO UNWRITTEN ORAL AGREEMENTS BETWEEN THE PARTIES.

(b)    Except as provided in Section 6.01, this Agreement shall become effective when it shall have been executed by the Administrative Agent and when the Administrative Agent shall have received counterparts hereof which, when taken together, bear the signatures of each of the other parties hereto, and thereafter shall be binding upon and inure to the benefit of the parties hereto and their respective successors and assigns.

Section 12.07    Severability. Any provision of this Agreement or any other Loan Document held to be invalid, illegal or unenforceable in any jurisdiction shall, as to such jurisdiction, be ineffective to the extent of such invalidity, illegality or unenforceability without affecting the validity, legality and enforceability of the remaining provisions hereof or thereof; and the invalidity of a particular provision in a particular jurisdiction shall not invalidate such provision in any other jurisdiction.

Section 12.08    Right of Setoff. If an Event of Default shall have occurred and be continuing, each Lender, the Issuing Bank and each of their respective Affiliates is hereby authorized at any time and from time to time, to the fullest extent permitted by law, to set off and apply any and all deposits (general or special, time or demand, provisional or final) at any time held and other obligations (of whatsoever kind, including, without limitation, obligations under Swap Agreements) at any time owing, by such Lender, the Issuing Bank or any such Affiliate, to or for the credit or the account of the Borrower or any other Loan Party against any and all of the obligations of the Borrower or any other Loan Party now or hereafter existing under this Agreement or any other Loan Document to such Lender or the Issuing Bank or their respective Affiliates, irrespective of whether or not such Lender, the Issuing Bank or Affiliate shall have made any demand under this Agreement or any other Loan Document and although such

 

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obligations of the Borrower may be contingent or unmatured or are owed to a branch office or Affiliate of such Lender or the Issuing Bank different from the branch office or Affiliate holding such deposit or obligated on such indebtedness; provided that in the event that any Defaulting Lender shall exercise any such right of setoff, (x) all amounts so setoff shall be paid over immediately to the Administrative Agent for further application in accordance with the provisions of Section 4.03 and, pending such payment, shall be segregated by such Defaulting Lender from its other funds and deemed held in trust for the benefit of the Administrative Agent, the Issuing Bank, and the Lenders, and (y) the Defaulting Lender shall provide promptly to the Administrative Agent a statement describing in reasonable detail the Obligations owing to such Defaulting Lender as to which it exercised such right of setoff. The rights of each Lender, the Issuing Bank and their respective Affiliates under this Section 12.08 are in addition to other rights and remedies (including other rights of setoff) that such Lender, the Issuing Bank or their respective Affiliates may have. Each Lender and the Issuing Bank agrees to notify the Borrower and the Administrative Agent promptly after any such setoff and application; provided that the failure to give such notice shall not affect the validity of such setoff and application.

Section 12.09    GOVERNING LAW; JURISDICTION; CONSENT TO SERVICE OF PROCESS.

(a)    THIS AGREEMENT AND THE NOTES SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF NEW YORK.

(b)    ANY LEGAL ACTION OR PROCEEDING WITH RESPECT TO THE LOAN DOCUMENTS SHALL BE BROUGHT IN THE SUPREME COURT OF THE STATE OF NEW YORK SITTING IN NEW YORK COUNTY OR OF THE UNITED STATES OF AMERICA FOR THE SOUTHERN DISTRICT OF NEW YORK, AND, BY EXECUTION AND DELIVERY OF THIS AGREEMENT, EACH PARTY HEREBY ACCEPTS FOR ITSELF AND (TO THE EXTENT PERMITTED BY LAW) IN RESPECT OF ITS PROPERTY, GENERALLY AND UNCONDITIONALLY, THE JURISDICTION OF THE AFORESAID COURTS. EACH PARTY HEREBY IRREVOCABLY WAIVES ANY OBJECTION, INCLUDING, WITHOUT LIMITATION, ANY OBJECTION TO THE LAYING OF VENUE OR BASED ON THE GROUNDS OF FORUM NON CONVENIENS, WHICH IT MAY NOW OR HEREAFTER HAVE TO THE BRINGING OF ANY SUCH ACTION OR PROCEEDING IN SUCH RESPECTIVE JURISDICTIONS. THIS SUBMISSION TO JURISDICTION IS NON-EXCLUSIVE AND DOES NOT PRECLUDE A PARTY FROM OBTAINING JURISDICTION OVER ANOTHER PARTY IN ANY COURT OTHERWISE HAVING JURISDICTION.

(c)    EACH PARTY IRREVOCABLY CONSENTS TO THE SERVICE OF PROCESS OF ANY OF THE AFOREMENTIONED COURTS IN ANY SUCH ACTION OR PROCEEDING BY THE MAILING OF COPIES THEREOF BY REGISTERED OR CERTIFIED MAIL, POSTAGE PREPAID, TO IT AT THE ADDRESS SPECIFIED IN SECTION 12.01 OR SUCH OTHER ADDRESS AS IS SPECIFIED PURSUANT TO SECTION 12.01 (OR ITS ASSIGNMENT AND ASSUMPTION), SUCH SERVICE TO BECOME EFFECTIVE THIRTY (30) DAYS AFTER SUCH MAILING. NOTHING HEREIN SHALL AFFECT THE RIGHT OF A PARTY OR ANY HOLDER OF A NOTE TO SERVE PROCESS IN ANY OTHER MANNER PERMITTED BY LAW OR TO COMMENCE LEGAL PROCEEDINGS OR OTHERWISE PROCEED AGAINST ANOTHER PARTY IN ANY OTHER JURISDICTION.

 

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(d)    WAIVER OF JURY TRIAL. EACH PARTY HEREBY (i) IRREVOCABLY AND UNCONDITIONALLY WAIVES, TO THE FULLEST EXTENT PERMITTED BY LAW, TRIAL BY JURY IN ANY LEGAL ACTION OR PROCEEDING RELATING TO THIS AGREEMENT OR ANY OTHER LOAN DOCUMENT AND FOR ANY COUNTERCLAIM THEREIN; (ii) CERTIFIES THAT NO PARTY HERETO NOR ANY REPRESENTATIVE OR AGENT OF COUNSEL FOR ANY PARTY HERETO HAS REPRESENTED, EXPRESSLY OR OTHERWISE, OR IMPLIED THAT SUCH PARTY WOULD NOT, IN THE EVENT OF LITIGATION, SEEK TO ENFORCE THE FOREGOING WAIVERS, AND (iii) ACKNOWLEDGES THAT IT HAS BEEN INDUCED TO ENTER INTO THIS AGREEMENT, THE LOAN DOCUMENTS AND THE TRANSACTIONS CONTEMPLATED HEREBY AND THEREBY BY, AMONG OTHER THINGS, THE MUTUAL WAIVERS AND CERTIFICATIONS CONTAINED IN THIS SECTION 12.09.

Section 12.10    Headings. Article and Section headings and the Table of Contents used herein are for convenience of reference only, are not part of this Agreement and shall not affect the construction of, or be taken into consideration in interpreting, this Agreement.

Section 12.11    Confidentiality; Material Non-Public Information. Each of the Administrative Agent, the Arranger, the Issuing Bank and the Lenders agrees to maintain the confidentiality of the Information (as defined below), except that Information may be disclosed (a) to its and its Affiliates’ directors, officers, employees and agents, including accountants, legal counsel and other advisors, its auditors and its Related Parties (it being understood that the Persons to whom such disclosure is made will be informed of the confidential nature of such Information and instructed to keep such Information confidential), (b) to the extent requested by any Governmental Authority (including any self-regulatory authority, such as the National Association of Insurance Commissioners), (c) to the extent required by applicable laws or regulations or by any subpoena or similar legal process, (d) to any other party to this Agreement or any other Loan Document, (e) in connection with the exercise of any remedies hereunder or under any other Loan Document or any suit, action or proceeding relating to this Agreement or any other Loan Document or the enforcement of rights hereunder or thereunder, (f) subject to an agreement containing provisions substantially the same as those of this Section 12.11, to (i) any assignee of or Participant in, or any prospective assignee of or Participant in, any of its rights or obligations under this Agreement or (ii) any actual or bona fide prospective counterparty (or its advisors) to any Swap Agreement relating to the Borrower and its obligations, (g) on a confidential basis to (1) any rating agency in connection with rating the Borrower or its Subsidiaries or the credit facilities provided for herein or (2) the CUSIP Service Bureau or any similar agency in connection with the issuance and monitoring of identification numbers with respect to the credit facilities provided for herein, (h) with the consent of the Borrower or (i) to the extent such Information (i) becomes publicly available other than as a result of a breach of this Section 12.11 or (ii) becomes available to the Administrative Agent, the Arranger, the Issuing Bank, any Lender or any Affiliate of the foregoing Persons on a nonconfidential basis from a source other than the Borrower. For the purposes of this Section 12.11, “Information” means all information received from the Borrower, any of its Affiliates, or any of its or their Related Parties or any Subsidiary relating to the Borrower’s, any of its Affiliates’, any of its or their Related Parties’ or any Subsidiary’s businesses, other than any

 

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such information that is available to the Administrative Agent, the Arranger, the Issuing Bank or any Lender on a nonconfidential basis prior to disclosure by the Borrower or any Subsidiary and other than information pertaining to this Agreement routinely provided by arrangers to data service providers, including league table providers, that serve the lending industry; provided that, in the case of information received from the Borrower, any of its Affiliates or any of its or their Related Parties or any Subsidiary after the date hereof, such information is clearly identified at the time of delivery as confidential. Any Person required to maintain the confidentiality of Information as provided in this Section 12.11 shall be considered to have complied with its obligation to do so if such Person has exercised the same degree of care to maintain the confidentiality of such Information as such Person would accord to its own confidential information.

Each Lender acknowledges that the Information furnished to it pursuant to this Agreement or the other Loan Documents may include material non-public information concerning the Borrower and its Affiliates and its or their Related Parties or its or their respective securities, and confirms that it has developed compliance procedures regarding the use of material non-public information and that it will handle such material non-public information in accordance with those procedures and applicable law, including Federal and state securities laws.

All information, including requests for waivers and amendments, furnished by the Borrower or the Administrative Agent pursuant to, or in the course of administering, this Agreement or the other Loan Documents will be syndicate-level information, which may contain material non-public information about the Borrower and its Related Parties or their respective securities. Accordingly, each Lender represents to the Borrower and the Administrative Agent that it has identified in its Administrative Questionnaire a credit contact who may receive information that may contain material non-public information in accordance with its compliance procedures and applicable law, including Federal and state securities laws.

Section 12.12    Interest Rate Limitation. It is the intention of the parties hereto that each Lender shall conform strictly to usury laws applicable to it. Accordingly, if the transactions contemplated hereby would be usurious as to any Lender under laws applicable to it (including the laws of the United States of America and the State of New York or any other jurisdiction whose laws may be mandatorily applicable to such Lender notwithstanding the other provisions of this Agreement), then, in that event, notwithstanding anything to the contrary in any of the Loan Documents or any agreement entered into in connection with or as security for the Notes, it is agreed as follows: (i) the aggregate of all consideration which constitutes interest under law applicable to any Lender that is contracted for, taken, reserved, charged or received by such Lender under any of the Loan Documents or agreements or otherwise in connection with the Notes shall under no circumstances exceed the maximum amount allowed by such applicable law, and any excess shall be canceled automatically and if theretofore paid shall be credited by such Lender on the principal amount of the Obligations (or, to the extent that the principal amount of the Obligations shall have been or would thereby be paid in full, refunded by such Lender to the Borrower); and (ii) in the event that the maturity of the Notes is accelerated by reason of an election of the holder thereof resulting from any Event of Default under this Agreement or otherwise, or in the event of any required or permitted prepayment, then such consideration that constitutes interest under law applicable to any Lender may never include more than the maximum amount allowed by such applicable law, and excess interest, if any, provided for in this Agreement or otherwise shall be canceled automatically by such Lender as of the date of such acceleration or prepayment

 

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and, if theretofore paid, shall be credited by such Lender on the principal amount of the Obligations (or, to the extent that the principal amount of the Obligations shall have been or would thereby be paid in full, refunded by such Lender to the Borrower). All sums paid or agreed to be paid to any Lender for the use, forbearance or detention of sums due hereunder shall, to the extent permitted by law applicable to such Lender, be amortized, prorated, allocated and spread throughout the stated term of the Loans evidenced by the Notes until Payment in Full so that the rate or amount of interest on account of any Loans hereunder does not exceed the maximum amount allowed by such applicable law. If at any time and from time to time (i) the amount of interest payable to any Lender on any date shall be computed at the Highest Lawful Rate applicable to such Lender pursuant to this Section 12.12 and (ii) in respect of any subsequent interest computation period the amount of interest otherwise payable to such Lender would be less than the amount of interest payable to such Lender computed at the Highest Lawful Rate applicable to such Lender, then the amount of interest payable to such Lender in respect of such subsequent interest computation period shall continue to be computed at the Highest Lawful Rate applicable to such Lender until the total amount of interest payable to such Lender shall equal the total amount of interest which would have been payable to such Lender if the total amount of interest had been computed without giving effect to this Section 12.12.

Section 12.13    EXCULPATION PROVISIONS. EACH OF THE PARTIES HERETO SPECIFICALLY AGREES THAT IT HAS A DUTY TO READ THIS AGREEMENT AND THE OTHER LOAN DOCUMENTS AND AGREES THAT IT IS CHARGED WITH NOTICE AND KNOWLEDGE OF THE TERMS OF THIS AGREEMENT AND THE OTHER LOAN DOCUMENTS; THAT IT HAS IN FACT READ THIS AGREEMENT AND IS FULLY INFORMED AND HAS FULL NOTICE AND KNOWLEDGE OF THE TERMS, CONDITIONS AND EFFECTS OF THIS AGREEMENT; THAT IT HAS BEEN REPRESENTED BY INDEPENDENT LEGAL COUNSEL OF ITS CHOICE THROUGHOUT THE NEGOTIATIONS PRECEDING ITS EXECUTION OF THIS AGREEMENT AND THE OTHER LOAN DOCUMENTS; AND HAS RECEIVED THE ADVICE OF ITS ATTORNEY IN ENTERING INTO THIS AGREEMENT AND THE OTHER LOAN DOCUMENTS; AND THAT IT RECOGNIZES THAT CERTAIN OF THE TERMS OF THIS AGREEMENT AND THE OTHER LOAN DOCUMENTS RESULT IN ONE PARTY ASSUMING THE LIABILITY INHERENT IN SOME ASPECTS OF THE TRANSACTION AND RELIEVING THE OTHER PARTY OF ITS RESPONSIBILITY FOR SUCH LIABILITY. EACH PARTY HERETO AGREES AND COVENANTS THAT IT WILL NOT CONTEST THE VALIDITY OR ENFORCEABILITY OF ANY EXCULPATORY PROVISION OF THIS AGREEMENT AND THE OTHER LOAN DOCUMENTS ON THE BASIS THAT THE PARTY HAD NO NOTICE OR KNOWLEDGE OF SUCH PROVISION OR THAT THE PROVISION IS NOT “CONSPICUOUS.

Section 12.14    Collateral Matters; Swap Agreements; Cash Management Agreements. The benefit of the Security Instruments and of the provisions of this Agreement relating to any Collateral securing the Obligations shall also extend to and be available to Secured Swap Parties and Secured Cash Management Providers on a pro rata basis (but subject to the terms of the Loan Documents, including, without limitation, provisions thereof relating to the application and priority of payments to the Persons entitled thereto) in respect of Secured Swap Obligations and Secured Cash Management Obligations. Except as provided in Section 12.02(b), no Secured Swap Party or Secured Cash Management Provider shall have any voting rights under any Loan

 

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Document as a result of the existence of any Secured Swap Obligation or Secured Cash Management Obligation owed to it. Except with respect to the exercise of setoff rights in accordance with Section 12.08 or with respect to a Secured Party’s right to file a proof of claim in an insolvency proceeding, no Secured Party shall have any right individually to realize upon any of the Collateral or to enforce any guarantee of the Obligations, it being understood and agreed that all powers, rights and remedies under the Loan Documents may be exercised solely by the Administrative Agent on behalf of the Secured Parties in accordance with the terms thereof.

Section 12.15    No Third Party Beneficiaries. This Agreement, the other Loan Documents, and the agreement of the Lenders to make Loans and the Issuing Bank to issue, amend, renew or extend Letters of Credit hereunder are solely for the benefit of the Borrower, and no other Person (including, without limitation, any Subsidiary of the Borrower, any obligor, contractor, subcontractor, supplier or materialsman) shall have any rights, claims, remedies or privileges hereunder or under any other Loan Document against the Administrative Agent, the Issuing Bank or any Lender for any reason whatsoever. There are no third party beneficiaries other than to the extent contemplated by the last sentence of Section 12.04(a).

Section 12.16    USA PATRIOT Act Notice. Each Lender hereby notifies the Borrower that pursuant to the requirements of the USA PATRIOT Act, it is required to obtain, verify and record information that identifies the Borrower and the Guarantors, which information includes the name and address of the Borrower and the Guarantors and other information that will allow such Lender to identify, the Borrower and the Guarantors in accordance with the USA PATRIOT Act.

Section 12.17    Non-Fiduciary Status. The arranging and other services regarding this Agreement provided by the Administrative Agent, the Arranger, and the Lenders are arm’s-length commercial transactions between the Borrower and its Affiliates, on the one hand, and the Administrative Agent, the Arranger, and the Lenders, on the other hand. The Borrower has consulted its own legal, accounting, regulatory and tax advisors to the extent it has deemed appropriate. The Borrower is capable of evaluating, and understands and accepts, the terms, risks and conditions of the transactions contemplated hereby and by the other Loan Documents; the Administrative Agent, the Arranger and each Lender is and has been acting solely as a principal and, except as expressly agreed in writing by the relevant parties, has not been, is not, and will not be acting as an advisor, agent or fiduciary for the Borrower or any of its Affiliates, or any other Person and neither the Administrative Agent, the Arranger nor any Lender has any obligation to the Borrower, or any of its Affiliates with respect to the transactions contemplated hereby except those obligations expressly set forth herein and in the other Loan Documents. The Administrative Agent, the Arranger and the Lenders and their respective Affiliates may be engaged in a broad range of transactions that involve interests that differ from those of the Borrower and its Affiliates, and none of the Administrative Agent, the Arranger, or any Lender has any obligation to disclose any of such interests to the Borrower or its Affiliates. To the fullest extent permitted by law, the Borrower hereby waives and releases any claims that it may have against the Administrative Agent, the Arranger or any Lender with respect to any breach or alleged breach of agency or fiduciary duty in connection with any aspect of any transaction contemplated hereby.

Section 12.18    Flood Insurance Provisions. Notwithstanding any provision in this Agreement or any other Loan Document to the contrary, in no event is any Building (as defined in the applicable Flood Insurance Regulation) or Manufactured (Mobile) Home (as defined in the

 

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applicable Flood Insurance Regulation) included in the definition of “Mortgaged Property” and no Building or Manufactured (Mobile) Home is hereby encumbered by this Agreement or any other Loan Document.

Section 12.19    Acknowledgement and Consent to Bail-In of Affected Financial Institutions. Notwithstanding anything to the contrary in any Loan Document or in any other agreement, arrangement or understanding among any such parties, each party hereto acknowledges that any liability of any Affected Financial Institution arising under any Loan Document, to the extent such liability is unsecured, may be subject to the Write-Down and Conversion Powers of the applicable Resolution Authority and agrees and consents to, and acknowledges and agrees to be bound by:

(a)    the application of any Write-Down and Conversion Powers by the applicable Resolution Authority to any such liabilities arising hereunder that may be payable to it by any party hereto that is an Affected Financial Institution; and

(b)    the effects of any Bail-In Action on any such liability, including, if applicable:

(i)    a reduction in full or in part or cancellation of any such liability;

(ii)    a conversion of all, or a portion of, such liability into shares or other instruments of ownership in such Affected Financial Institution, its parent undertaking, or a bridge institution that may be issued to it or otherwise conferred on it, and that such shares or other instruments of ownership will be accepted by it in lieu of any rights with respect to any such liability under this Agreement or any other Loan Document; or

(iii)    the variation of the terms of such liability in connection with the exercise of the Write-Down and Conversion Powers of the applicable Resolution Authority.

Section 12.20    Acknowledgement Regarding Any Supported QFCs. To the extent that the Loan Documents provide support, through a guarantee or otherwise, for any Swap Agreement or any other agreement or instrument that is a QFC (such support, “QFC Credit Support”, and each such QFC, a “Supported QFC”), the parties acknowledge and agree as follows with respect to the resolution power of the Federal Deposit Insurance Corporation under the Federal Deposit Insurance Act and Title II of the Dodd-Frank Wall Street Reform and Consumer Protection Act (together with the regulations promulgated thereunder, the “U.S. Special Resolution Regimes”) in respect of such Supported QFC and QFC Credit Support (with the provisions below applicable notwithstanding that the Loan Documents and any Supported QFC may in fact be stated to be governed by the laws of the State of New York and/or of the United States or any other state of the United States): In the event a Covered Entity that is party to a Supported QFC (each, a “Covered Party”) becomes subject to a proceeding under a U.S. Special Resolution Regime, the transfer of such Supported QFC and the benefit of such QFC Credit Support (and any interest and obligation in or under such Supported QFC and such QFC Credit Support, and any rights in property securing such Supported QFC or such QFC Credit Support) from such Covered Party will be effective to the same extent as the transfer would be effective under the U.S. Special Resolution Regime if the Supported QFC and such QFC Credit Support (and any such interest, obligation and

 

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rights in property) were governed by the laws of the United States or a state of the United States. In the event a Covered Party or a BHC Act Affiliate of a Covered Party becomes subject to a proceeding under a U.S. Special Resolution Regime, Default Rights under the Loan Documents that might otherwise apply to such Supported QFC or any QFC Credit Support that may be exercised against such Covered Party are permitted to be exercised to no greater extent than such Default Rights could be exercised under the U.S. Special Resolution Regime if the Supported QFC and the Loan Documents were governed by the laws of the United States or a state of the United States. Without limitation of the foregoing, it is understood and agreed that rights and remedies of the parties with respect to a Defaulting Lender shall in no event affect the rights of any Covered Party with respect to a Supported QFC or any QFC Credit Support.

Section 12.21    Releases.

(a)    Release Upon the Release Date. Upon the Release Date, any security interest and any guarantee granted pursuant to the Loan Documents in respect of the Collateral or the Obligations shall be released; provided that, the Administrative Agent shall take any action reasonably requested by the Borrower in order to effect or evidence the foregoing, in each case, without recourse or warranty by the Administrative Agent and at the sole expense of the Borrower.

(b)    Further Assurances. If any of the Collateral shall be sold, transferred or otherwise Disposed of by the Borrower or any other Loan Party in a transaction permitted by this Agreement or any other Loan Document, then the Administrative Agent, at the request and sole expense of the Borrower, shall promptly execute and deliver to the Borrower all releases or other documents reasonably necessary or desirable for the release of the Liens created by the applicable Security Instrument on such Collateral. A Guarantor shall be released from its obligations under this Agreement and the other Loan Documents in the event that all of the Equity Interests of such Guarantor shall be sold, transferred or otherwise Disposed of in a transaction permitted by this Agreement and the Administrative Agent, at the request and sole expense of the Borrower, shall promptly execute and deliver to the Borrower all releases or other documents reasonably necessary or desirable to evidence the release of, or otherwise release, such Guarantor from its obligations under the Loan Documents.

Section 12.22    Electronic Execution; Electronic Records; Counterparts.

(a)    This Agreement, any Loan Document and any other Communication, including Communications required to be in writing, may be in the form of an Electronic Record and may be executed using Electronic Signatures. Each of the Borrower, on behalf of itself and the other Loan Parties, and each Credit Party agrees that any Electronic Signature on or associated with any Communication shall be valid and binding on such Person to the same extent as a manual, original signature, and that any Communication entered into by Electronic Signature, will constitute the legal, valid and binding obligation of such Person enforceable against such Person in accordance with the terms thereof to the same extent as if a manually executed original signature was delivered. Any Communication may be executed in as many counterparts as necessary or convenient, including both paper and electronic counterparts, but all such counterparts are one and the same Communication. For the avoidance of doubt, the authorization under this paragraph may include, without limitation, use or acceptance of a manually signed paper Communication which has been converted into electronic form (such as scanned into PDF format), or an electronically

 

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signed Communication converted into another format, for transmission, delivery and/or retention. Each of the Arranger, each Agent and each Credit Party may, at its option, create one or more copies of any Communication in the form of an imaged Electronic Record (“Electronic Copy”), which shall be deemed created in the ordinary course of such Person’s business, and destroy the original paper document. All Communications in the form of an Electronic Record, including an Electronic Copy, shall be considered an original for all purposes, and shall have the same legal effect, validity and enforceability as a paper record. Notwithstanding anything contained herein to the contrary, neither the Administrative Agent nor the Issuing Bank is under any obligation to accept an Electronic Signature in any form or in any format unless expressly agreed to by such Person pursuant to procedures approved by it; provided, further, without limiting the foregoing, (i) to the extent the Administrative Agent or the Issuing Bank has agreed to accept such Electronic Signature, each of the Arranger, each Agent and each Credit Party shall be entitled to rely on any such Electronic Signature purportedly given by or on behalf of any Loan Party and/or any Credit Party without further verification and (ii) upon the request of any Credit Party, any Electronic Signature shall be promptly followed by such manually executed counterpart.

(b)    Neither the Administrative Agent nor the Issuing Bank shall be responsible for or have any duty to ascertain or inquire into the sufficiency, validity, enforceability, effectiveness or genuineness of any Loan Document or any other agreement, instrument or document (including, for the avoidance of doubt, in connection with the Administrative Agent’s or the Issuing Bank’s reliance on any Electronic Signature transmitted by telecopy, emailed .pdf or any other electronic means). The Administrative Agent and the Issuing Bank shall be entitled to rely on, and shall incur no liability under or in respect of this Agreement or any other Loan Document by acting upon, any Communication (which writing may be a fax, any electronic message, Internet or intranet website posting or other distribution or signed using an Electronic Signature) or any statement made to it orally or by telephone and believed by it to be genuine and signed or sent or otherwise authenticated (whether or not such Person in fact meets the requirements set forth in the Loan Documents for being the maker thereof).

(c)    Each of the Borrower, on behalf of itself and the other Loan Parties, and each Credit Party hereby waives (i) any argument, defense or right to contest the legal effect, validity or enforceability of this Agreement and/or any other Loan Document based solely on the lack of paper original copies of this Agreement and/or such other Loan Document, and (ii) any claim against any Agent, Arranger, Credit Party and/or any of their respective Related Parties for any liabilities arising solely from any Agent’s, Arranger’s or Credit Party’s reliance on or use of Electronic Signatures, including any liabilities arising as a result of the failure of the Loan Parties to use any available security measures in connection with the execution, delivery or transmission of any Electronic Signature.

Section 12.23    Assignment and Assumption from KMF Land to Borrower; Amendment and Restatement; Existing Credit Agreement.

(a)    On the Effective Date, (i) KMF Land hereby irrevocably assigns, transfers and conveys all of its rights, duties, liabilities and obligations as the borrower under the Existing Loan Documents to the Borrower, and the Borrower hereby irrevocably accepts such assignment from KMF Land and agrees to be bound by all of the terms, conditions and provisions of, and assumes all of the rights, duties, liabilities and obligations of KMF Land as the borrower under the

 

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Existing Loan Documents, in each case to the extent amended, restated and superseded in connection with the transactions contemplated hereby with the same force and effect as if originally named the “Borrower” under the Existing Credit Agreement (and, for the avoidance of doubt, KMF Land shall cease to be the “Borrower” thereunder), (ii) this Agreement shall not constitute a novation, discharge, rescission, extinguishment or substitution of the parties’ rights and obligations as to payment of the “Loans”, “Letters of Credit” and the “Obligations” (as each such term is defined in the Existing Credit Agreement) or evidence payment of all or any portion of any of KMF Land’s or any of the other Existing Loan Parties’ obligations and liabilities under the Existing Credit Agreement and such amendment and restatement shall operate to renew, amend, modify, and extend all of the rights, duties, liabilities and obligations of the Existing Loan Parties under the Existing Credit Agreement and under the Existing Loan Documents, which rights, duties, liabilities and obligations as to payment of the “Loans”, “Letters of Credit” and the “Obligations” (as each such term is defined in the Existing Credit Agreement) are hereby renewed, amended, modified and extended, and shall not act as a novation thereof, (iii) the “Loans”, “Letters of Credit” and the “Obligations” (as each such term is defined in the Existing Credit Agreement) shall remain outstanding and be continued as the same indebtedness as Loans, Letters of Credit and other Obligations hereunder and shall bear interest and be subject to such other fees as set forth in this Agreement and (iv) the Liens securing the Obligations under and as defined in the Existing Credit Agreement and the rights, duties, liabilities and obligations of the Borrower and the Guarantors as to payment of the “Loans”, “Letters of Credit” and other “Obligations” (as each such term is defined in the Existing Credit Agreement) and the Existing Loan Documents to which they are a party shall not be extinguished but shall be carried forward and shall secure such Obligations and rights, duties, obligations and liabilities as amended, renewed, extended and restated hereby.

(b)    Any obligations under the “Fee Letters” as defined in the Existing Credit Agreement shall be of no further force and effect and such “Fee Letters” are hereby terminated. Any “Note” as defined in the Existing Credit Agreement shall be deemed for all purposes superseded and replaced by the Note (if any) issued to the applicable Lender under this Agreement, without further action required by any payee thereof, and all “Notes” under the Existing Credit Agreement shall be of no further force and effect.

(c)    KMF Land represents and warrants that, immediately prior to the Effective Date, there are no claims or offsets against, or defenses or counterclaims to, its obligations (or the obligations of any Guarantor) under the Existing Credit Agreement or any of the other Existing Loan Documents. Borrower represents and warrants that, as of the Effective Date, there are no claims or offsets against, or defenses or counterclaims to, its obligations (or the obligations of any Guarantor) under the Existing Credit Agreement or any of the other Existing Loan Documents.

(d)    Notwithstanding anything to the contrary contained in this Agreement or in any other Loan Document, any Lender may exchange, continue or roll over all or a portion of its Loans in connection with the amendment and restatement of the Existing Credit Agreement on the Effective Date and any other refinancing, extension, loan modification or similar transaction permitted by the terms of this Agreement, pursuant to a cashless settlement mechanism approved by the Borrower, the Administrative Agent and such Lender.

 

156


(e)    For the avoidance of doubt, any basket which permits a certain amount of a given type of transaction over any period of time (however denominated), without being deemed to prohibit any transaction occurring prior to the Effective Date, shall be reset such that such basket provision shall cover only time periods from the Effective Date until the Maturity Date.

(f)    For the avoidance of doubt, as of the Effective Date, no Person shall be a party to this Agreement or any other Loan Document in any capacity other than in any capacity in which such Person executes this Agreement or any other Loan Document.

[SIGNATURES BEGIN NEXT PAGE]

 

157


The parties hereto have caused this Agreement to be duly executed as of the day and year first above written.

 

BORROWER:                                                           SITIO ROYALTIES OPERATING PARTNERSHIP, LP
    By: Sitio Royalties GP, LLC, its general partner
    By:  

/s/ Carrie Osicka

    Name:   Carrie Osicka
    Title:   Chief Financial Officer

 

SIGNATURE PAGE TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT


KMF LAND, LLC
By:  

/s/ Carrie Osicka

Name:   Carrie Osicka
Title:   Chief Financial Officer

 

SIGNATURE PAGE TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT


BANK OF AMERICA, N.A.,
as Administrative Agent, Issuing Bank and a Lender
By:  

/s/ Kimberly Miller

Name:   Kimberly Miller
Title:   Director

 

SIGNATURE PAGE TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT


BARCLAYS BANK PLC,
as a Lender
By:  

/s/ Craig Malloy

Name:   Craig Malloy
Title:   Director

 

SIGNATURE PAGE TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT


CAPITAL ONE, NATIONAL ASSOCIATION,
as a Lender
By:  

/s/ Christopher Kuna

Name:   Christopher Kuna
Title:   Senior Director

 

SIGNATURE PAGE TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT


FIFTH THIRD BANK, NATIONAL ASSOCIATION,
as a Lender
By:  

/s/ Richard Butler

Name:   Richard Butler
Title:   Senior Vice President

 

SIGNATURE PAGE TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT


KEYBANK NATIONAL ASSOCIATION,
as a Lender
By:  

/s/ David M. Bornstein

Name:   David M. Bornstein
Title:   Senior Vice President

 

SIGNATURE PAGE TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT


CITIBANK, N.A.,
as a Lender
By:  

/s/ Cliff Vaz

Name:   Cliff Vaz
Title:   Vice President

 

SIGNATURE PAGE TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT


ROYAL BANK OF CANADA,
as a Lender
By:  

/s/ Jason York

Name:   Jason York
Title:   Authorized Signatory

 

SIGNATURE PAGE TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT


CREDIT SUISSE AG, New York Branch,
as a Lender
By:  

/s/ Doreen Barr

Name:   Doreen Barr
Title:   Authorized Signatory
By:  

/s/ Michael Dieffenbacher

Name:   Michael Dieffenbacher
Title:   Authorized Signatory

 

SIGNATURE PAGE TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT


COMERICA BANK,
as a Lender
By:  

/s/ Caroline M. McClurg

Name:   Caroline M. McClurg
Title:   Senior Vice President

 

SIGNATURE PAGE TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT


ANNEX I

LIST OF MAXIMUM CREDIT AMOUNTS

 

NAME OF LENDER

   APPLICABLE
PERCENTAGE
    MAXIMUM
CREDIT
AMOUNT
     ELECTED
COMMITMENT
 

Bank of America, N.A.

     16.666666669   $ 125,000,000.00      $ 50,000,000.00  

Barclays Bank PLC

     13.333333333   $ 100,000,000.00      $ 40,000,000.00  

Capital One, National Association

     13.333333333   $ 100,000,000.00      $ 40,000,000.00  

Fifth Third Bank, National Association

     13.333333333   $ 100,000,000.00      $ 40,000,000.00  

KeyBank National Association

     13.333333333   $ 100,000,000.00      $ 40,000,000.00  

Citibank, N.A.

     8.333333333   $ 62,500,000.00      $ 25,000,000.00  

Royal Bank of Canada

     8.333333333   $ 62,500,000.00      $ 25,000,000.00  

Credit Suisse AG, New York Branch

     8.333333333   $ 62,500,000.00      $ 25,000,000.00  

Comerica Bank

     5.000000000   $ 37,500,000.00      $ 15,000,000.00  
  

 

 

   

 

 

    

 

 

 

TOTAL

     100.000000000   $ 750,000,000.00      $ 300,000,000.00  
  

 

 

   

 

 

    

 

 

 

 

ANNEX I

Exhibit 16.1

 

LOGO

  

Deloitte & Touche LLP

1601 Wewatta Street

Suite 400

Denver, CO 80202

United States

 

Tel: +303 292 5400

Fax: +303 312 4000

www.deloitte.com

June 10, 2022

Securities and Exchange Commission

100 F Street, N.E.

Washington, D.C. 20549-7561

Dear Sirs/Madams:

We have read item 4.01 of Falcon Minerals Corporation’s (now known as Sitio Royalties Corp.) Form 8-K dated June 10, 2022 and have the following comments:

 

  1.

We agree with the statements made under the heading “Dismissal of Independent Registered Public Accounting Firm”.

 

  2.

We have no basis on which to agree or disagree with the statements made under the heading “Engagement of New Independent Registered Public Accounting Firm”.

Yours truly,

/s/ DELOITTE & TOUCHE LLP

 

1

Exhibit 23.1

Consent of Independent Registered Public Accounting Firm

We consent to the incorporation by reference in the registration statement on Forms S-8 (333-228663) and S-3 (333-259668) of Sitio Royalties Corp. of our report dated March 22, 2022, with respect to the consolidated financial statements of Kimmeridge Mineral Fund, L.P., which report appears in this Current Report (Form 8-K) of Sitio Royalties Corp dated June 10, 2022.

/s/ KPMG LLP

Denver, Colorado

June 10, 2022

Exhibit 23.2

 

LOGO

CONSENT OF INDEPENDENT PETROLEUM ENGINEERS

As independent petroleum engineers, we hereby consent to the references to our firm, in the context in which they appear, and to the references to, and the inclusion of, our reserve reports and oil, natural gas and NGL reserves estimates and forecasts of economics as of December 31, 2021 and December 31, 2020, included in or made part of the registration statements (No. 333-259668) on Form S-3 and (No. 333-228663) on Form S-8 of Sitio Royalties Corp. (formerly known as Falcon Minerals Corporation), including any amendments thereto (the “Registration Statements”), which appears in this Current Report on Form 8-K of Sitio Royalties Corp.

 

CAWLEY, GILLESPIE & ASSOCIATES, INC.
Texas Registered Engineering Firm

/s/ J. Zane Meekins

J. Zane Meekins, P. E.
Executive Vice President

Fort Worth, Texas

June 10, 2022

Exhibit 99.1

Desert Peak Minerals and Falcon Minerals Corporation Announce Completion of Merger

06/07/2022

Combined Company Rebranded Sitio Royalties Corp. (NASDAQ: STR)

Sitio Poised to Become Leading Oil-Weighted Mineral and Royalty Interest Consolidator

DENVER—(BUSINESS WIRE)— Desert Peak Minerals (“Desert Peak”) and Falcon Minerals Corporation (“Falcon”) today announced the successful completion of their merger, creating Sitio Royalties Corp. (Nasdaq: STR) (the “Company” or “Sitio”), a premier, shareholder returns-driven company focused on large-scale consolidation of high-quality oil & gas mineral and royalty interests across diversified operators.

With a proven track record of completing large, accretive acquisitions in the Permian Basin, Sitio is poised to become a top consolidator in the space. Guided by a disciplined financial philosophy and strong balance sheet, Sitio will focus on maximizing value for all stakeholders and returning significant cash to shareholders.

On June 3, 2022, prior to the consummation of the merger, Falcon effected a four-to-one reverse stock split of Falcon’s Class A common stock and Class C common stock and formally rebranded as Sitio Royalties Corp. The Company’s Class A common stock and warrants will initially continue trading on Nasdaq under the ticker symbols “STR” and “STRDW.” In connection with the closing of the merger, the Company entered into a new credit facility with a $300 million borrowing base.

In accordance with the terms of the merger agreement, Desert Peak became a subsidiary of Falcon’s operating partnership (“OpCo”). Desert Peak’s equity holders received 61,905,339 shares of the Company’s Class C common stock and a corresponding number of common units representing limited partner interests in OpCo.

Chris Conoscenti, CEO of Sitio, said: “Sitio is guided by its commitments to best-in-class leadership and governance standards, capital discipline and a thoughtful approach to value-maximizing M&A. Sitio’s distinguished profile as a leading consolidator in the minerals and royalties space will only continue to strengthen over time with the execution of our proven strategy, focusing on large-scale accretive acquisitions across diversified operators.”

Noam Lockshin, Chairman of Sitio’s Board of Directors, said: “In line with Kimmeridge’s operating philosophy, Sitio has already adopted a best-in-class governance model that is structured to drive long-term shareholder returns and strong alignment with all its stakeholders. When leadership and directors are incentivized to drive outperformance and to optimize shareholder returns, as they are at Sitio, everyone wins. We believe this is the backbone of any successful public company, and Sitio is leading the way in this space.”


Sitio Senior Leadership Team and Board of Directors

As previously announced, Sitio will be managed by the legacy Desert Peak management team, led by current Chief Executive Officer, Christopher Conoscenti. Noam Lockshin, a Partner at Kimmeridge, Sitio’s largest equity holder, will serve as Chairman of the Board of Directors. The Board comprises seven members with strong independence, diversity and deep expertise across energy, finance and governance: Noam Lockshin, Morris R. Clark, Christopher L. Conoscenti, Alice E. Gould, Allen W. Li, Claire R. Harvey and Steven R. Jones.

Stock Exchange Listing Transfer

As previously announced, the Company plans to transfer the listing of its Class A common stock and warrants from Nasdaq to the New York Stock Exchange (“NYSE”) and NYSE American LLC, respectively, on or about June 14, 2022, where the Company’s Class A common stock will retain the same ticker symbol “STR,” and the warrants will trade under the new ticker symbol “STR WS.” The Company’s Class A common stock and warrants will be delisted from Nasdaq in connection with listing on NYSE and NYSE American LLC.

About Sitio Royalties Corp.

Sitio is a shareholder returns-driven company focused on large-scale consolidation of high-quality oil & gas mineral and royalty interests across premium basins, with a diversified set of top-tier operators. With a clear objective of generating cash flow from operations that can be returned to shareholders and reinvested, Sitio has accumulated over 140,000 net royalty acres (“NRAs,” when normalized to a 1/8th royalty equivalent) through the consummation of over 180 acquisitions to date. More information about Sitio, including an updated investor presentation, is available at www.sitio.com.

Forward Looking Statements

This new release contains statements that may constitute “forward-looking statements” for purposes of federal securities laws. Forward-looking statements include, but are not limited to, statements that refer to projections, forecasts, or other characterizations of future events or circumstances, including any underlying assumptions. The words “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “intends,” “may,” “might,” “plan,” “seeks,” “possible,” “potential,” “predict,” “project,” “prospects,” “guidance,” “outlook,” “should,” “would,” “will,” and similar expressions may identify forward-looking statements, but the absence of these words does not mean that a statement is not forward-looking. These statements include, but are not limited to, statements about the Company’s expected benefits of the merger between Falcon and Desert Peak; future dividends; and future plans, expectations, and objectives for the Company’s operations, including statements about strategy, synergies, future operations, financial position, prospects, and plans. While forward-looking statements are based on assumptions and analyses made by us that we believe to be reasonable under the circumstances, whether actual results and developments will meet our expectations and predictions depend on a number of risks and uncertainties that could cause our actual results, performance, and financial condition to


differ materially from our expectations and predictions. See “Risk Factors” in Falcon’s definitive proxy statement filed with the U.S. Securities and Exchange Commission (the “SEC”) on May 5, 2022 for a discussion of risk factors related to the merger between Falcon and Desert Peak and Desert Peak’s business. See also Part I, Item 1A “Risk Factors” in Falcon’s Annual Report on Form 10-K for the fiscal year ended December 31, 2021 and Part II, Item 1A “Risk Factors” in Falcon’s Quarterly Reports on Form 10-Q, each filed with the SEC for a discussion of risk factors that affect Falcon’s business. Any forward-looking statement made in this news release speaks only as of the date on which it is made. Factors or events that could cause actual results to differ may emerge from time to time, and it is not possible to predict all of them. Sitio undertakes no obligation to publicly update any forward-looking statement, whether as a result of new information, future development, or otherwise, except as may be required by law.

IR contact:

Ross Wong

(720) 640-7647

IR@sitio.com

Media contact:

Daniel Yunger or Hallie Wolff

Kekst CNC

Kekst-Sitio@kekstcnc.com

Source: Sitio Royalties Corp.

Slide 1

A Leading Mineral and Royalty Business Exhibit 99.2


Slide 2

Disclaimer FORWARD-LOOKING STATEMENTS This presentation relates to Sitio Royalties Corp. (the “Company” or “Sitio”) following the merger and related transactions (collectively, the “Merger”) between the Company (formerly Falcon Minerals Corporation) and Desert Peak Minerals and release includes certain statements that may constitute “forward-looking statements” for purposes of the federal securities laws. Forward-looking statements include, but are not limited to, statements that refer to projections, forecasts, or other characterizations of future events or circumstances, including any underlying assumptions. The words “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “intends,” “may,” “might,” “plan,” “seeks,” “possible,” “potential,” “predict,” “project,” “prospects,” “guidance,” “outlook,” “should,” “would,” “will,” and similar expressions may identify forward-looking statements, but the absence of these words does not mean that a statement is not forward-looking. These statements include, but are not limited to, statements about; the expected benefits of the Merger; future dividends; and future plans, expectations, and objectives for the Company’s operations after completion of the Merger, including statements about strategy, synergies, future operations, financial position, estimated revenues, projected production, projected costs, prospects, plans, and objectives of management. While forward-looking statements are based on assumptions and analyses made by us that we believe to be reasonable under the circumstances, whether actual results and developments will meet our expectations and predictions depend on a number of risks and uncertainties which could cause our actual results, performance, and financial condition to differ materially from our expectations. See “Risk Factors” in the Company’s proxy statement on Schedule 14A, filed with the SEC on May 5, 2022, its Annual Report on Form 10-K for the fiscal year ended December 31, 2020, as amended on Form 10-K/A, and in its Quarterly Reports on Form 10-Q, filed with the SEC for a discussion of risk factors that affect our business. Any forward-looking statement made in this news release speaks only as of the date on which it is made. Factors or events that could cause actual results to differ may emerge from time to time, and it is not possible to predict all of them. Neither Desert Peak nor Falcon undertake any obligation to publicly update any forward-looking statement, whether as a result of new information, future development, or otherwise, except as may be required by law. INDUSTRY AND MARKET DATA The information, data and statistics contained herein are derived from various internal (including data that Sitio has internally collected) and external third party sources. While Sitio believes such third party information is reliable, there can be no assurance as to the accuracy or completeness of the indicated information. Sitio has not independently verified the accuracy or completeness of the information provided by third party sources. No representation is made by Sitio’s management as to the reasonableness of the assumptions made within or the accuracy or completeness of any projections or modeling or any other information contained herein. Any information, data or statistics on past performance or modeling contained herein is not an indication as to future performance. Sitio assumes no obligation to update the information in this presentation. BASIS OF PRESENTATION Unless otherwise noted, all NRA counts and gross and net well counts are as of 06/06/22. All NRA metrics shown on an 1/8ths royalty equivalent basis. NON-GAAP MEASURES This presentation includes financial measures that are not presented in accordance with U.S. generally accepted accounting principles (“GAAP”). While Sitio believes such non-GAAP measures are useful for investors, they are not measures of financial performance under GAAP and should not be considered in isolation or as an alternative to any measure of such performance derived in accordance with GAAP. These non-GAAP measures have limitations as analytical tools and you should not consider them in isolation or as substitutes for analysis of results as reported under GAAP. These non-GAAP measures may not be comparable to similarly titled measures used by other companies in our industry or across different industries.


Slide 3

Mineral and royalty interest ownership provides unique, cost advantaged oil and gas exposure Differentiated, large-scale consolidation strategy across diversified operators Disciplined capital allocation focused on value creation and returns Best-in-class governance model led by experienced Board and management Premier asset base focused at the front end of operators’ cost curves Sitio’s investment thesis


Slide 4

1Q22 Production and NRAs (net royalty acres) Sitio acquires and manages oil and gas minerals and royalties in U.S. shale plays with a focus on the Permian Basin A leading oil-weighted mineral and royalty consolidator focused on large scale acquisitions (1) Share price and enterprise value as of 06/06/22. (2)Annualized 1Q22 adjusted EBITDA calculated as the sum of ~$60mm of Desert Peak Minerals (“DPM”) 1Q22 Adjusted EBITDA plus ~$18mm of FLMN Adjusted EBITDA plus ~$3mm of DPM 1Q22 cash G&A plus ~$2mm of FLMN 1Q22 cash G&A less Sitio’s quarterly public cash G&A assumption of ~$3.75mm all multiplied by 4. (3)Net debt calculated as of 06/06/22 and assumes completion of acquisitions signed to date. (4) NRAs include all acquisitions signed to date. 15,487 boe/d Permian Basin Eagle Ford Shale Appalachian Key statistics(1) Sitio asset footprint by county 50% oil 141,800 NRAs(4) 76% Permian (3) (2)


Slide 5

No physical operations or environmental liabilities Mineral interests are perpetual real property interests No field staff or lease operating expenses and 100% of capital expenditures are discretionary Data management systems improve royalty management capabilities Highly fragmented mineral and royalty ownership with limited number of buyers capable of large-scale acquisitions G&A expenses do not increase linearly with company scale Highest margin component of the energy value chain with limited direct exposure to cost inflation Ability to return majority of cash flow to investors Mineral and royalty businesses are a structurally advantaged asset class SIMPLICITY EFFICIENCY SCALABILITY PROFITABILITY


Slide 6

Mineral and royalty ownership provides compelling margins and organic growth upside without development capex 2021 EBITDA Margin(1) 2016 – 2021 EBITDA CAGR(3) (2) Source:FactSet as of 06/06/22. Note:Statistics represent median of peer group. Mineral and royalty index includes: BSM, KRP, FLMN, VNOM, MNRL, and TPL. Large Cap E&P includes: APA, CLR, COP, CTRA, DVN, EOG, EQT, FANG, HES, MRO, OVV, OXY, PXD. SMID Cap E&P includes: AR, CDEV, CHK, CNX, CPE, CPG, KOS, MGY, MTDR, MUR, OAS, PDCE, RRC, SM, SWN, WLL. (1) EBITDA margin represents EBITDA divided by revenue. (2) EBITDA growth for BSM, KRP and VNOM represents 2016 - 2021 annualized EBITDA CAGR. EBITDA growth for FLMN and MNRL represents 2018 - 2021 annualized EBITDA CAGR. TPL not included in EBITDA CAGR. EBITDA sourced from FactSet. (3) EBITDA CAGR represents the compound annual growth rate from 01/01/16 to 12/31/21 other than as noted in footnote 2. Mineral and royalty businesses have better EBITDA margins… …And EBITDA growth without development capex


Slide 7

Mineral and royalty business total returns are resilient through economic cycles 2016 – 2021 Average FCF Yield(2) (1) Mineral and royalty FCF yield has remained resilient through the economic cycle, including during the Covid-19 Pandemic Creating leading FCF yield… …And attractive returns for investors Source:Company filings and presentations and FactSet as of 06/06/22. Note:Statistics represent median of peer group. Mineral and royalty index includes: BSM, KRP, FLMN, VNOM, MNRL, and TPL. Large Cap E&P includes: APA, CLR, COP, CTRA, DVN, EOG, EQT, FANG, HES, MRO, OVV, OXY, PXD. SMID Cap E&P includes: AR, CDEV, CHK, CNX, CPE, CPG, KOS, MGY, MTDR, MUR, OAS, PDCE, RRC, SM, SWN, WLL. (1) Minerals peer set for average free cash flow yield represented by BSM, KRP and VNOM for 2016 – 2021, FLMN and MNRL for 2018 – 2021, and TPL in 2021 only. (2) Free cash flow defined as cash flow from operations less capex. Free cash flow yield represents full year free cash flow divided by year-end equity value per FactSet. Figures shown represent the median of the 2016 - 2021 average free cash flow yield for the companies in the peer group. The 2016 - 2021 average free cash flow yield for each company represents the average for all years between 2016 and 2021 where the company had publicly available financials. Total returns (share price performance plus dividends) by year


Slide 8

Mineral and royalty businesses also act as an inflation hedge (CPI % Inflation) (WTI Price) Source: FactSet and Bureau of Labor Statistics as of 06/06/22. CPI vs. WTI 2017 – Current Key takeaways Mineral and royalty revenue is driven by energy prices, acting as an inflation hedge for shareholders Minerals are not directly exposed to drilling and completion or lease operating expense cost inflation like E&P companies


Slide 9

Target greater than mid-teens unlevered returns Prioritize Permian-focused assets to leverage extensive in-basin experience Thoroughly diligence land, geology, and engineering data Understand depth of line-of-sight inventory Avoid single-operator and/or high-NRI concentration risk Strong preference for relationship-driven, privately negotiated acquisitions vs. broad auction processes Sitio’s disciplined underwriting approach results in strong returns (boe/d) (1) Cumulative first 6-month production (boe/d) ~20% average outperformance (1)Actuals based on IHS reported actuals as of 03/31/22. Key underwriting criteria Sitio’s recent large acquisitions are all outperforming underwriting assumptions


Slide 10

Sitio has a proven and peer leading consolidation effort Over 195,000 NRAs evaluated for acquisition, but bid/ask spread was too wide 1Q22: 105,500 Current: 141,800 (% NRA increase) Note: For Sitio, includes all acquisitions signed through 06/06/22. (1)Peers include BSM, KRP, MNRL, TPL, and VNOM. BSM NRAs only include NRAs in Black Stone Resource Plays as defined in BSM’s publicly filed documents. Sitio NRAs since inception: 180+ acquisitions to date Change in NRAs by public peers since 2019(1) (Cumulative NRAs) (NRAs acquired by quarter) Peer 1 Peer 5 Peer 4 Peer 3 Peer 2


Slide 11

Sitio is well positioned to consolidate the highly fragmented mineral and royalty sector… ($ in Bn) ~$66 Bn in 2021 Less than 10 public oil and gas royalty companies vs. 45+ public E&P operators Only a fraction of U.S. oil and gas royalty payments go to current public royalty companies Source:Company filings, FactSet, and the EIA as of 06/06/22. (1)Minerals include BSM, DMLP, KRP, MNRL, STR, TPL, and VNOM. E&P includes AMPY, APA, AR, BATL, BRY, CDEV, CHK, CIVI, CNX, COP, CPE, CRC, CRGY, CRK, CTRA, DEN, DVN, EOG, EPM, EQT, ERF, ESTE, FANG, GPOR, HES, HPK, KOS, LPI, MGY, MRO, MTDR, MUR, OAS, OVV, OXY, PDCE, PXD, REI, REPX, RRC, SBOW, SD, SM, SWN, TALO, WLL, and WTI. (2)Total U.S. oil and gas revenues are calculated taking EIA monthly oil and gas production data, multiplying by average monthly WTI and HHUB spot prices according to the EIA. Royalty payments calculated assuming an average lease royalty of 18.75% and that 20% of oil and gas production occurs on federal acreage where all royalties go to the government. Aggregate public market capitalization(1) Estimated U.S. royalty revenue(2)


Slide 12

…Particularly in its core target area of the Permian Basin Non-acquirable acreage Acquirable acreage ~7.5mm total ~5.3mm acquirable Delaware Midland ~5.6mm total ~5.1mm acquirable ~20,000 and ~45,000 unique mineral owners across the Delaware and Midland, respectively Sitio Acquirable NRAs Delaware and Midland Basins Non-acquirable NRAs Non-acquirable acreage is comprised of federal and state-owned minerals and royalties where the government does not sell minerals or NPRIs and minerals owned by CVX, TPL, and VNOM Acquirable acreage is defined as any acreage in which Sitio can purchase mineral rights or NPRIs that is not owned by CVX, TPL, or VNOM Source: Company filings as of 03/31/22. Unique mineral owners based on public tax roll data. Note: CVX mineral ownership based on calculating the surface acreage of CVX minerals ownership in Culberson, Loving, and Reeves counties and applying a 12.5% royalty interest. Assumes maximum royalty interest of 25% on all gross acres, adjusted to 1/8th royalty equivalent basis. Includes all acquisitions signed as of 03/31/22. Permian Basin NRAs Permian Basin addressable market


Slide 13

Significant cash G&A ($/boe) reduction while well count grows ~4.4x Acquisitions will drive improvements in Sitio’s scalable cost structure 24 26 Employees <35 2,438 7,706 Gross Wells 10,791 40% decline in cash G&A $/Boe (NRAs) (Cash G&A $/Boe) (3) (1) Includes all acquisitions signed to date. (2) 1Q22 pro forma cash G&A based on the Sitio’s estimated annual public cash G&A amount, which is equal to $15mm. Sitio’s estimated cash G&A is not inclusive of any stock-based compensation, one-time transaction costs or any FLMN cash G&A costs incurred prior to closing. (1)


Slide 14

Assets are in basins that have comprised a majority of total U.S. spuds since 01/01/16 Sitio’s mineral and royalty position attracts E&P operator capital (% of U.S. spuds) Source: Enverus well data as of 05/26/22. Appalachian


Slide 15

Sitio’s large spud and permit inventory provides visibility into near-term production growth and development potential Net PDP wells drilled prior to 01/01/19 Net PDP wells drilled since 01/01/19 Only 40 net PDP wells since 1/1/19 vs. 19 line-of-sight wells currently Note: Wells as of 06/06/22 and includes wells on all acquisitions signed to date. All wells normalized to 5,000’.


Slide 16

Sitio has substantial line-of-sight inventory in partnership with top-tier operators Other 11 Net Spuds Other 8 Net Permits Note: All well data as of 06/06/22 and includes wells on all acquisitions signed to date. All wells normalized to 5,000’.


Slide 17

Focused on maximizing value and maintaining balance sheet strength Sitio’s financial philosophy and capitalization Generate robust free cash flow Return at least 65% of discretionary cash flow(1) to shareholders via dividends Maintain underwriting discipline for accretive acquisitions Maintain conservative and financially flexible capital structure Discretionary cash flow defined as adjusted EBITDA less cash interest and cash taxes. Capitalization as of 06/06/22. Credit facility borrowings give effect to transaction expenses and assumes completion of acquisitions signed to date. Borrowing base gives effect to new combined company revolving credit facility. Financial philosophy Capitalization table ü ü ü ü (3) (2) (4)


Slide 18

Sitio’s capital allocation framework Management team is incentivized to maximize dividends and stock price appreciation Direct alignment of interests with public shareholders without limiting financial flexibility First priority for retained cash is to protect the balance sheet Retained cash also allows Sitio to opportunistically make cash acquisitions Sitio Capital Allocation 35% 65% Sitio expects to retain approximately Sitio expects to pay a dividend of at least of its discretionary cash flow to shareholders of its discretionary cash flow 35% 65%


Slide 19

Sitio’s governance model provides strong alignment with shareholders Management Incentive compensation is 100% equity based, with emphasis on total shareholder return instead of relative returns or growth with no relationship to shareholder returns Initial equity awards are based on trading price around closing of merger; no vested legacy stock compensation or incentive units Experienced, dedicated management team is 100% focused on mineral and royalty business, not on an operated or non-operated position, other business lines or companies Board and management compensation is structured to drive total long-term shareholder returns Capital allocation policy prioritizes return of capital to shareholders SHAREHOLDERS Board of Directors Best in Class Governance Model Incentivizes Board and Management to Optimize Shareholder Returns 6 of 7 members of the board of directors are independent Director compensation is substantially all equity


Slide 20

Leading example of environmental and social responsibility Environmental Social Employee base and Board reflective of a culture that values diversity Over 50% of Sitio’s employees are women 4 out of 7 board members are diverse Management team and employees have experience across the oil and gas value chain to provide unique perspectives on minerals Zero environmental liabilities No scope 1 and negligible scope 2 emissions Sitio’s lease form provides an economic disincentive for flaring gas Target minerals under operators with strong environmental track records


Slide 21

Sitio’s management team and Board of Directors Chris Conoscenti CEO and Director 21 years of experience Carrie Osicka CFO 17 years of experience Jarret Marcoux EVP of Engineering and Acquisitions 17 years of experience Britton James EVP of Land 16 years of experience Brett Riesenfeld EVP, General Counsel, and Secretary 12 years of experience Steven Jones 27 years of experience Morris Clark 31 Years of experience Alice Gould 38 years of experience Noam Lockshin Chairman 15 years of experience Allen Li 11 years of experience Chris Conoscenti 21 years of experience Claire Harvey 21 years of experience Management team Board of Directors


Slide 22

Appendix


Slide 23

Delaware Basin overview Acreage footprint by drilling spacing unit Asset summary Top operators(2) (1)NRAs pro forma for all acquisitions signed to date. (2)Top operators based on publicly reported production data for the quarter ending 03/31/22. (1)


Slide 24

Midland Basin overview Acreage footprint by drilling spacing unit Asset summary Top operators(2) (1)NRAs pro forma for all acquisitions signed to date. (2)Top operators based on publicly reported production data for the quarter ending 03/31/22. (1)


Slide 25

Eagle Ford shale overview Acreage footprint by drilling spacing unit Asset summary Top operators(1) (1)Top operators based on publicly reported production data for the quarter ending 03/31/22.


Slide 26

Appalachian Basin overview Acreage footprint by drilling spacing unit Asset summary Top operators(1) (1)Top operators based on publicly reported production data for the quarter ending 03/31/22.


Slide 27

Contact Information Ross Wong Senior Director of Corporate Finance and Investor Relations Phone: (720) 640-7647 Email: IR@sitio.com Corporate Headquarters: 1401 Lawrence Street, Suite 1750 Denver, CO 80202 Houston Office: 609 Main Street, Suite 3950 Houston, TX 77002


Slide 28

Exhibit 99.3

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors

Kimmeridge Mineral Fund, LP:

Opinion on the Consolidated Financial Statements

We have audited the accompanying consolidated balance sheets of Kimmeridge Mineral Fund, LP and subsidiaries (the Partnership) as of December 31, 2021 and 2020, the related consolidated statements of operations, changes in equity, and cash flows for each of the years in the three year period ended December 31, 2021, and the related notes (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Partnership as of December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the years in the three year period ended December 31, 2021, in conformity with U.S. generally accepted accounting principles.

Basis for Opinion

These consolidated financial statements are the responsibility of the Partnership’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Partnership in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.

Critical Audit Matters

The critical audit matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to those charged with governance and that: (1) relate to accounts or disclosures that are material to the consolidated financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.

Estimated proved oil and natural gas reserves used in the depletion of evaluated oil and natural gas properties

As discussed in Note 2 to the consolidated financial statements, the Partnership uses the successful efforts method of accounting for its oil and natural gas producing properties and depletes capitalized costs using the unit-of-production basis over total proved oil and natural gas reserves. The Partnership had $1,147.1 million of net oil and natural gas properties as of December 31, 2021, and recorded depletion expense of proved oil

 

1


and natural gas properties of $40.3 million for the year ended December 31, 2021. The Partnership engages independent petroleum engineers to prepare the estimates of proved oil and natural gas reserves.

We identified the assessment of the estimated proved oil and natural gas reserves used in the depletion of proved oil and natural gas properties as a critical audit matter. A high degree of subjective auditor judgement was required in evaluating the estimate of proved oil and natural gas reserves, as auditor judgment was required to evaluate the assumptions used by the Partnership related to forecasted production and oil and natural gas prices, inclusive of price differentials.

The following are the primary procedures we performed to address this critical audit matter. We evaluated (1) the professional qualifications of the lead internal petroleum engineer as well as the engineer assigned to the Partnership by the independent petroleum engineering firm engaged by the Partnership, (2) the knowledge, skills, and ability of the lead internal petroleum engineer, the engineer assigned to the Partnership by the independent petroleum engineering firm, as well as the independent petroleum engineering firm engaged by the Partnership, and (3) the relationship of the independent petroleum engineering firm and the engineer assigned to the Partnership. We assessed the method used by the Partnership’s independent petroleum engineers to estimate the proved oil and natural gas reserves for consistency with industry and regulatory standards. We compared the Partnership’s historical production forecasts to actual production volumes to assess the Partnership’s ability to accurately forecast and we compared the future forecasted production used by the Partnership in the current period to historical production. We evaluated the oil and natural gas prices used by the Partnership’s independent petroleum engineers by comparing them to publicly available prices and tested the relevant price differentials by comparing them to historical differentials. We read and considered the findings of the independent petroleum engineers engaged by the Partnership in connection with our evaluation of the Partnership’s reserve estimates. We analyzed the depletion expense calculation for compliance with regulatory standards, and checked the accuracy of the depletion expense calculation.

Accrued revenue

As discussed in Note 3 to the consolidated financial statements, the Partnership recognizes oil, natural gas and NGL revenues from its mineral and royalty interests when control of the product is transferred to the customer and the performance obligations under the terms of the contracts with customers are satisfied. As a mineral and royalty interest owner, the Partnership has limited visibility into the timing of when new wells start producing as production statements may not be received for 30 to 90 days or more after the date production is delivered. As a result, the Partnership is required to estimate the amount of production delivered to the purchaser and the price that will be received for the sale of the product. The expected sales volumes and prices for these properties are estimated and recorded within accrued revenue and accounts receivable, net. The difference between the Partnership’s estimates of mineral and royalty income and the actual amounts received for oil, natural gas and NGL sales are recorded in the month that the mineral and royalty payment is received from the customer. At December 31, 2021, the Partnership had accrued revenue and accounts receivable, net of $36.2 million, a portion of which related to accrued revenue.

We identified the assessment of accrued revenue as a critical audit matter. A high degree of subjective auditor judgment was required to evaluate the estimated volume of production delivered to the related customers, as well as the price that will be received for the sale of the oil, natural gas, and NGLs produced.

The following are the primary procedures we performed to address this critical audit matter. We evaluated the design of certain internal controls related to the Partnership’s oil, natural gas and NGL revenue accrual process, including controls related to the development of the estimates of delivered production volumes and the price that will be received for the sale of such volumes. We compared the Partnership’s historical revenue accruals to actual cash collections to assess the Partnership’s ability to accurately estimate. We independently developed an expectation of accrued revenue and compared such expectation to the amounts recorded by the Partnership. For a selection of transactions where third-party evidence was available, we compared management’s estimate of accrued revenue related to delivered production to third-party

 

2


evidence. We evaluated the prices used by the Partnership to estimate the price to be received for the sale of the oil, natural gas, and NGLs produced by independently developing an expectation of price using publicly available market prices and historical differentials.

/s/ KPMG LLP

We have served as the Partnership’s auditor since 2020.

Denver, Colorado

March 22, 2022

 

3


KIMMERIDGE MINERAL FUND, LP

CONSOLIDATED BALANCE SHEETS

(In thousands)

 

     December 31,  
     2021     2020  

ASSETS

    

Current assets

    

Cash and cash equivalents

   $ 12,379     $ 7,531  

Accrued revenue and accounts receivable, net

     36,202       8,505  

Other current assets

     235       138  
  

 

 

   

 

 

 

Total current assets

     48,816       16,174  
  

 

 

   

 

 

 

Property and equipment

    

Oil and natural gas properties, successful efforts method:

    

Unproved properties

     817,873       399,229  

Proved properties

     447,369       254,854  

Other property and equipment

     8,187       7,990  

Accumulated depreciation, depletion and amortization

     (121,536     (80,630
  

 

 

   

 

 

 

Net oil and gas properties and other property and equipment

     1,151,893       581,443  
  

 

 

   

 

 

 

Other long-term assets

    

Deferred financing costs

     2,145       1,011  
  

 

 

   

 

 

 

Total long-term assets

     2,145       1,011  
  

 

 

   

 

 

 

TOTAL ASSETS

   $ 1,202,854     $ 598,628  
  

 

 

   

 

 

 

LIABILITIES AND EQUITY

    

Current liabilities

    

Accrued expenses and other liabilities

   $ 4,140     $ 2,035  

Due to affiliates

     442       55  
  

 

 

   

 

 

 

Total current liabilities

     4,582       2,090  
  

 

 

   

 

 

 

Long-term debt

     134,000       33,500  

Deferred rent

     1,129       641  

Total liabilities

     139,711       36,231  
  

 

 

   

 

 

 

COMMITMENTS AND CONTINGENCIES (NOTE 10)

    

Equity

    

Partners’ capital

     560,622       562,397  
  

 

 

   

 

 

 

Noncontrolling interests

     502,521       —    
  

 

 

   

 

 

 

Total equity

     1,063,143       562,397  
  

 

 

   

 

 

 

TOTAL LIABILITIES AND EQUITY

   $ 1,202,854     $ 598,628  
  

 

 

   

 

 

 

The accompanying notes are an integral part of the consolidated financial statements.

 

4


KIMMERIDGE MINERAL FUND, LP

CONSOLIDATED STATEMENTS OF OPERATIONS

 

     Year Ended December 31,  
     2021     2020     2019  
     (In thousands)  

Revenue:

      

Oil, natural gas and natural gas liquids revenues

   $ 118,548     $ 44,194     $ 50,886  

Lease bonus and other income

     2,040       1,505       5,319  

Water sales

     —         —         3,475  

Commodity derivatives losses

     —         (2,573     —    
  

 

 

   

 

 

   

 

 

 

Total revenue

     120,588       43,126       59,680  
  

 

 

   

 

 

   

 

 

 

Operating Expenses:

      

Management fees to affiliates

     7,480       7,480       7,480  

Depreciation, depletion and amortization

     40,906       32,049       26,201  

General and administrative

     4,143       4,981       2,349  

General and administrative – affiliates

     8,855       4,407       8,167  

Severance taxes, ad valorem taxes and operating expense

     6,858       3,151       5,249  

Impairment of oil and natural gas properties

     —         812       —    

Deferred offering costs write off

     2,396       2,747       —    

Bad debt expense (recovered)

     —         (251     405  

Gain on sale of property

     —         (42     —    
  

 

 

   

 

 

   

 

 

 

Total operating expenses

     70,638       55,334       49,851  
  

 

 

   

 

 

   

 

 

 

Net income (loss) from operations

     49,950       (12,208     9,829  

Other income (expense):

      

Interest income (expense)

     (1,893     (1,968     (868
  

 

 

   

 

 

   

 

 

 

Net income (loss) before income tax expense

     48,057       (14,176     8,961  

Income tax expense

     (562     (38     (171
  

 

 

   

 

 

   

 

 

 

Net income (loss) including noncontrolling interests

     47,495     $ (14,214   $ 8,790  
  

 

 

   

 

 

   

 

 

 

Net income attributable to noncontrolling interests

     18,781       —         —    
  

 

 

   

 

 

   

 

 

 

Net income (loss) attributable to partners

   $ 28,714     $ (14,214   $ 8,790  
  

 

 

   

 

 

   

 

 

 

The accompanying notes are an integral part of the consolidated financial statements.

 

5


KIMMERIDGE MINERAL FUND, LP

STATEMENTS OF CHANGES IN EQUITY

FOR THE YEARS ENDED DECEMBER 31, 2021, 2020 AND 2019

 

     General
Partners
    Limited
Partners
    Noncontrolling
interests
    Total Equity  
           (In thousands)  

Equity at January 1, 2019

   $ 4,623     $ 385,458       —       $ 390,081  
  

 

 

   

 

 

   

 

 

   

 

 

 

Capital contributions

     2,388       162,352       —         164,740  

Net income

     235       8,555       —         8,790  

Equity at December 31, 2019

   $ 7,246     $ 556,365       —       $ 563,611  
  

 

 

   

 

 

   

 

 

   

 

 

 

Capital contributions

     166       12,834       —         13,000  

Net loss

     (86     (14,128     —         (14,214
  

 

 

   

 

 

   

 

 

   

 

 

 

Equity at December 31, 2020

   $ 7,326     $ 555,071       —       $ 562,397  
  

 

 

   

 

 

   

 

 

   

 

 

 

Capital contributions

     78       7,922       —         8,000  

Capital distributions

     (862     (66,638     (60,882     (128,382
  

 

 

   

 

 

   

 

 

   

 

 

 

Issuance of equity in consolidated subsidiary

     849       65,621       507,163       573,633  
  

 

 

   

 

 

   

 

 

   

 

 

 

Deemed distribution in connection with common control acquisition

     (478     (36,981     37,459       —    

Net income

     462       28,252       18,781       47,495  
  

 

 

   

 

 

   

 

 

   

 

 

 

Equity at December 31, 2021

   $ 7,375     $ 553,247       502,521     $ 1,063,143  
  

 

 

   

 

 

   

 

 

   

 

 

 

The accompanying notes are an integral part of the consolidated financial statements.

 

6


KIMMERIDGE MINERAL FUND, LP

CONSOLIDATED STATEMENTS OF CASH FLOW

 

     Year ended December 31,  
     2021     2020     2019  
     (In thousands)  

Cash flows from operating activities

      

Net income (loss)

   $ 47,495     $ (14,214   $ 8,790  

Adjustments to reconcile net income (loss) to net cash provided by operating activities:

      

Depreciation, depletion and amortization

     40,906       32,049       26,201  

Impairment of oil and natural gas properties

     —         812       —    

Deferred offering costs write off

     2,396       2,747       —    

Loss on extinguishment of debt

     —         —         308  

Bad debt expense (recovered)

     —         (251     405  

Gain on sale of property

     —         (42     —    

Change in operating assets and liabilities:

      

Accounts receivable

     (27,697     4,436       (1,340

Due from affiliates

     —         —         610  

Other current assets

     (97     14       (60

Other long-term assets

     440       256       53  

Accrued expenses and other liabilities

     1,673       (328     (121

Due to affiliates

     325       (51     (107

Deferred rent

     488       588       52  
  

 

 

   

 

 

   

 

 

 

Net cash provided by operating activities

     65,929       26,016       34,791  
  

 

 

   

 

 

   

 

 

 

Cash flows from investing activities

      

Purchases of oil and gas properties

     (38,470     (35,543     (266,538

Proceeds from sale of oil and gas properties

     (137     14,069       22,019  

Purchases of other property and equipment

     (136     (293     (1,041

Proceeds from sale of other property and equipment

     —         210       —    

Escrow deposits

     —         —         (3,067
  

 

 

   

 

 

   

 

 

 

Net cash used in investing activities

     (38,743     (21,557     (248,627
  

 

 

   

 

 

   

 

 

 

Cash flows from financing activities

      

Capital contributions

     8,000       13,000       164,740  

Issuance of equity in consolidated subsidiary

     1,467       —         —    

Distributions to Partners

     (67,500     —         —    

Distributions to noncontrolling interests

     (60,882     —         —    

Borrowings on credit facility

     147,000       10,000       60,000  

Repayments on credit facility, net

     (46,500     (36,500     —    

Payments of deferred financing costs

     (1,588     (316     (1,284

Deferred initial public offering costs

     (2,335     (1,245     (1,502
  

 

 

   

 

 

   

 

 

 

Net cash used in financing activities

     (22,338     (15,061     221,954  
  

 

 

   

 

 

   

 

 

 

Net change in cash, cash equivalents and restricted cash

     4,848       (10,602     8,118  

Cash, cash equivalents and restricted cash, beginning of year

     7,531       18,133       10,015  
  

 

 

   

 

 

   

 

 

 

Cash, cash equivalents and restricted cash end of year

   $ 12,379     $ 7,531     $ 18,133  
  

 

 

   

 

 

   

 

 

 

Supplemental disclosure of non-cash transactions:

      

Escrow deposits reclassified to oil and gas properties:

   $ —       $ 3,067     $ —    

Increase in current liabilities for additions to property and equipment:

     446       2,145       2,184  

Oil and gas properties acquired through issuance of equity in consolidated subsidiary:

     572,166       —         —    

Oil and gas properties acquired through deemed distribution in connection with common control transaction:

     37,459       —         —    

Supplemental disclosure of cash flow information:

      

Cash paid for income taxes:

   $ 101     $ 230     $ 175  

Cash paid for interest expense:

     1,268       1,687       676  

The accompanying notes are an integral part of the consolidated financial statements.

 

7


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2021, 2020, AND 2019

 

1.

Organization

Kimmeridge Mineral Fund, LP (together with its subsidiaries, the “Partnership”) is a Delaware limited partnership operating under the Third Amendment to the Second Amended and Restated Limited Partnership Agreement (the “Partnership Agreement”) dated as of July 19, 2019. The Partnership formed on November 1, 2016 and commenced operation on November 11, 2016. The primary purpose of the Partnership is to acquire, own and manage mineral and royalty interests in the Permian Basin, located in West Texas and southeastern New Mexico of the United States. Mineral interests are real property interests that are typically perpetual and grant ownership of the oil and natural gas underlying a tract of land and the rights to explore for, drill for, and produce oil and natural gas on that land or to lease those exploration and development rights to a third party. When those rights are leased to third party operators, usually for a one to three-year term, the Partnership typically receives an upfront cash payment, known as a lease bonus, and the Partnership retains a mineral royalty, which entitles the Partnership to a cost-free percentage (up to 25%) of production or revenue from production free of lease operating expenses. The Partnership also owns surface rights which generate revenues from the sale of water produced from the Partnership’s water supply assets and from rights-of-way, easements and other rights.

The Partnership Agreement provides that the Partnership will continue (unless earlier dissolved) for ten years from the final closing date provided, however, that Kimmeridge Mineral GP, LLC (the “General Partner” or “Management”), may, in its discretion, extend the term of the Partnership for two additional one-year periods. In addition, the General Partner may extend the term of the Partnership for a third additional three-year period (the “Final Extension”); provided however, that the General Partner shall provide notice of such a proposed extension to the Limited Partners at least 60 calendar days before the expiration of the then current term. The Final Extension shall automatically take effect unless a majority of the Limited Partnership Advisory Committee (“LPAC”) members notify the General Partner in writing within 30 calendar days of receipt of the extension notice of their decision not to allow the Final Extension. Except as may be required by law or expressly provided for in the Partnership Agreement, the liability of each Limited Partner is limited to its Capital Commitment.

 

2.

Basis of Presentation and Summary of Significant Accounting Policies

Basis of Presentation

The consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (“GAAP”). In the opinion of management, the accompanying consolidated financial statements include all adjustments (consisting of normal and recurring accruals) considered necessary to present fairly the Partnership’s financial position as of December 31, 2021 and 2020, and the results of its operations and its cash flows for the years ended December 31, 2021, 2020, and 2019. The Partnership has no items of other comprehensive income or loss; therefore, its net income or loss is equal to its comprehensive income or loss.

Use of Estimates

The preparation of financial statements in conformity with GAAP requires Management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates.

The Partnership’s estimates and classification of oil and natural gas reserves are, by necessity, projections based on geologic and engineering data, and there are uncertainties inherent in the interpretation of such

 

8


data as well as the projection of future rates of production. Reserve engineering is a subjective process of estimating underground accumulations of oil and natural gas that are difficult to measure. The accuracy of any reserve estimate is a function of the quality of available data, engineering, and geological interpretation and judgment. Estimates of economically recoverable oil and natural gas reserves and future net cash flows necessarily depend upon a number of variable factors and assumptions. These factors and assumptions include historical production from the area compared with production from other producing areas, the assumed effect of regulations by governmental agencies, and assumptions governing future oil and natural gas prices. For these reasons, estimates of the economically recoverable quantities of expected oil and natural gas and estimates of the future net cash flows may vary substantially.

Any significant variance in the assumptions could materially affect the estimated quantity of reserves, which could affect the carrying value of the Partnership’s oil and natural gas properties and/or the rate of depletion related to oil and natural gas properties.

Principles of Consolidation

The accompanying consolidated financial statements include the accounts of the Partnership’s wholly-owned subsidiaries and any entities in which the Partnership owns a controlling interest. All intercompany accounts and transactions have been eliminated in consolidation. Noncontrolling interests in the Partnership’s consolidated financial statements represents the interests in a subsidiary of the Partnership, DPM HoldCo, LLC (“DPM HoldCo”), which are owned by outside parties. Noncontrolling interests in consolidated subsidiaries is included as a component of equity in the Partnership’s consolidated balance sheets.

Risks and Uncertainties

The ongoing global spread of the novel coronavirus (“COVID-19”), has caused a continuing disruption to the oil and natural gas industry and to our business by, among other things, contributing to a significant decrease in global crude oil demand and the price for oil in 2020. This disruption has been somewhat alleviated in 2021. However, the current price environment remains uncertain as responses to the COVID-19 pandemic and newly emerging variants of the virus continue to evolve. Additionally, significant geopolitical events may cause increased volatility in the price of oil and natural gas.

The markets for oil, natural gas and natural gas liquids (“NGL”) have experienced significant price fluctuations. Such price volatility is expected to continue into the future. Lower commodity prices may reduce the amount of oil, natural gas and NGL that can be produced economically by operators. Increases or decreases in commodity prices could impact the Partnership’s financial performance and expected operating results, which may include future reserves estimates and potential recognition of impairment charges related to the Partnership’s mineral and royalty interests.

Recent Accounting Pronouncements

In February 2016, the FASB issued ASU 2016-02, Leases, which requires all leasing arrangements to be presented on the balance sheet as liabilities along with a corresponding asset. ASU 2016-02 does not apply to leases of mineral rights to explore for or use crude oil and natural gas. The ASU will replace most existing lease guidance in GAAP when it becomes effective. In January 2018, the FASB issued ASU 2018-01, Land Easement Practical Expedient for Transition to Topic 842, to provide an optional practical expedient to not evaluate existing or expired land easements that were not previously accounted for as leases under Topic 840. In July 2018, the FASB issued ASU 2018-11 Leases: Targeted Improvements, which provides for another transition method, in addition to the existing transition method, by allowing entities to initially apply the new leases standard at the adoption date and recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption (i.e. comparative periods presented in the financial statements will continue to be in accordance with current GAAP (Topic 840, Leases)). The new

 

9


standards become effective for the Partnership during the fiscal year ending December 31, 2022 and interim periods within the fiscal year ending December 31, 2023. Early adoption is permitted. We are currently evaluating the impact that the adoption of this standard will have on our financial statements.

In June 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses, which amends current impairment guidance by adding an impairment model (known as the current expected credit loss model (“CECL”) that is based on expected losses rather than incurred losses. Under the new guidance, an entity recognizes as an allowance its estimate of lifetime expected credit losses, which the FASB believes will result in more timely recognition of such losses. ASU 2016-13 is effective for annual periods beginning after December 15, 2022 and interim periods within those annual periods. The Partnership is currently evaluating the impact of the adoption of this standard but does not believe it will have a material impact on the Partnership’s financial statements.

In March 2020, the FASB issued ASU 2020-04, Facilitation of the Effects of Reference Rate Reform on Financial Reporting. In response to the cessation of the London Interbank Offered Rate (“LIBOR”) by December 31, 2021, the FASB issued this update to provide optional expedients and exceptions for applying GAAP to contract modifications, hedging relations, and other affected transactions. The Partnership currently only has one contract subject to LIBOR, its revolving credit facility, that may be impacted by this ASU. Modifications of debt contracts should be accounted for by prospectively adjusting the effective interest rate. This update is effective immediately, but may be adopted through December 31, 2022, and allows for elections to be made by the Partnership in terms of how the ASU is adopted. Once elected for a Topic or Industry Subtopic, the update must be applied prospectively for all eligible contract modifications. The Partnership is currently evaluating the impact of the adoption of this standard but does not believe it will have a material impact on the Partnership’s financial statements.

Cash and Cash Equivalents

The Partnership considers all highly-liquid instruments purchased with an original maturity of three months or less to be cash equivalents. The Partnership maintains cash and cash equivalents in bank deposit accounts which, at times, may exceed the federally insured limits. The Partnership has not experienced any significant losses from such investments.

Accrued Revenue and Accounts Receivable

Accrued revenue and accounts receivable represent amounts due to the Partnership and are uncollateralized, consisting primarily of royalty revenue receivable. Royalty revenue receivable consists of royalties due from operators for oil, natural gas and NGL volumes sold to purchasers. Those purchasers remit payment for production to the operator of the properties and the operator, in turn, remits payment to the Partnership. Receivables from third parties for which we did not receive actual production information, either due to timing delays or due to the unavailability of data at the time when revenues are recognized, are estimated.

The Partnership routinely assesses the recoverability of all material accounts receivable to determine their collectability. The Partnership accrues a reserve to the allowance for doubtful accounts when it is probable that a receivable will not be collected and the amount of the reserve may be reasonably estimated. The Partnership had an allowance for doubtful accounts related to its KMF Water, LLC (“KMF Water”) receivables of $0.2 million and $0.2 million as of December 31, 2021 and 2020, respectively. There were no such allowances for KMF Land, LLC’s (“KMF Land”) royalty revenue receivables as of December 31, 2021 and 2020.

Oil and Gas Properties

The Partnership uses the successful efforts method of accounting for oil and natural gas producing properties, as further defined under ASC 932, Extractive Activities—Oil and Natural Gas. Under this

 

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method, costs to acquire mineral interests in oil and natural gas properties are capitalized. The costs of non-producing mineral interests and associated acquisition costs are capitalized as unproved properties pending the results of leasing efforts and drilling activities of Exploration and Production (“E&P”) operators on our interests. As unproved properties are determined to have proved reserves, the related costs are transferred to proved oil and gas properties by basin. Capitalized costs for proved oil and natural gas mineral interests are depleted on a unit-of-production basis over total proved reserves. For depletion of proved oil and gas properties, interests are grouped in a reasonable aggregation of properties with common geological structural features or stratigraphic conditions. Depletion expense totaled approximately $40.3 million, $31.4 million, and $25.7 million for the years ended December 31, 2021, 2020, and 2019, respectively.

Other Property and Equipment

Other property and equipment is recorded at cost, which includes water supply assets (water wells and water storage pits), and leasehold improvements. Depreciation and amortization are calculated using the straight-line method over the estimated useful lives of the assets. Leasehold improvements are depreciated over the shorter of the lease term or the useful lives of the assets. For the years ended December 31, 2021, 2020, and 2019, the Partnership recorded approximately $0.6 million, $0.6 million, and $0.5 million respectively, in depreciation for water assets and other property and equipment.

The costs to drill water wells are capitalized while drilling is in progress. If a water well is determined to be unsuccessful or unproductive prior to being placed in service, the associated costs will be charged to expense in the period the determination is made. No expense was recognized in connection with unsuccessful water wells for the years ended December 31, 2021, 2020, and 2019. Additionally, we evaluate our other property and equipment for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset that has been placed in service may not be recoverable. No impairment charge was recorded for the years ended December 31, 2021, 2020, and 2019.

Impairment of Oil and Gas Properties

The Partnership evaluates its producing properties for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. When assessing proved properties for impairment, the Partnership compares the expected undiscounted future cash flows of the proved properties to the carrying amount of the proved properties to determine recoverability. If the carrying amount of proved properties exceeds the expected undiscounted future cash flows, the carrying amount is written down to the properties’ estimated fair value, which is measured as the present value of the expected future cash flows of such properties. The factors used to determine fair value include estimates of proved reserves, future commodity prices, timing of future production, and a risk-adjusted discount rate. There was no impairment of proved properties for the years ended December 31, 2021, 2020, and 2019. The proved property impairment test is primarily impacted by future commodity prices, changes in estimated reserve quantities, estimates of future production, overall proved property balances, and depletion expense. If pricing conditions decline or are depressed, or if there is a negative impact on one or more of the other components of the calculation, we may incur proved property impairments in future periods.

Unproved oil and gas properties are assessed periodically for impairment of value, and a loss is recognized at the time of impairment by charging capitalized costs to expense. Impairment is assessed based on when facts and circumstances indicate that the carrying value may not be recoverable, at which point an impairment loss is recognized to the extent the carrying value exceeds the estimated recoverable value. Factors used in the assessment include but are not limited to commodity price outlooks, current and future operator activity in the Permian Basin, and analysis of recent mineral transactions in the surrounding area. The Partnership recognized no impairment of unproved properties for the year ended December 31, 2021 and 2019. The Partnership recognized approximately $0.8 million of unproved property impairment for the year ended December 31, 2020. This impairment was related to capitalized acquisition costs for a prospective mineral interest acquisition that the Partnership did not complete.

 

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Derivative Financial Instruments

In order to manage its exposure to oil, natural gas, and NGLs price volatility, the Partnership may periodically enter into derivative transactions, which may include commodity swap agreements, basis swap agreements, and other similar agreements which help manage the price risk associated with the Partnership’s production. These derivatives are not entered into for trading or speculative purposes. To the extent legal right of offset exists with a counterparty, the Partnership reports derivative assets and liabilities on a net basis. The Partnership has exposure to credit risk to the extent that the counterparty is unable to satisfy its settlement obligations. The Partnership actively monitors the creditworthiness of counterparties and assesses the impact, if any, on its derivative positions.

The Partnership records derivative instruments on its consolidated balance sheets as either assets or liabilities measured at fair value and records changes in the fair value of derivatives in current earnings as they occur. Changes in the fair value of commodity derivatives, including gains or losses on settled derivatives, are classified as revenues on the Partnership’s consolidated statements of operations. The Partnership’s derivatives have not been designated as hedges for accounting purposes. In October 2020, KMF Land terminated all of its outstanding oil and basis swap derivative contracts. KMF was not party to any derivative contracts as of December 31, 2021 and 2020.

Accrued Expenses and Other Liabilities

The Partnership’s accrued expenses and other liabilities consisted of the following as of the dates indicated (in thousands):

 

     December 31, 2021      December 31, 2020  

Ad valorem taxes payable

   $ 1,750      $ 1,200  

General and administrative

     904        445  

Other taxes payable

     529        68  

Acquisition costs

     391        —    

Interest expense

     274        88  

Deferred rent expense

     128        63  

Other

     164        171  
  

 

 

    

 

 

 

Total accrued expenses and other liabilities

   $ 4,140      $ 2,035  
  

 

 

    

 

 

 

Income Taxes

The Partnership is organized as a pass-through entity for income tax purposes. As a result, the partners are responsible for federal and state income taxes attributable to their share of the Partnership’s taxable income. However, the Partnership is required to pay Texas State franchise taxes and certain New Mexico income taxes. The Partnership recognized approximately $562 thousand, $38 thousand, and $171 thousand of Texas state franchise taxes and New Mexico income taxes for the years ended December 31, 2021, 2020, and 2019, respectively.

Revenue Recognition

Mineral and royalty interests represent the right to receive revenues from the sale of oil, natural gas and NGL, less production taxes and post-production expenses. The prices of oil, natural gas, and NGL from the properties in which we own a mineral or royalty interest are primarily determined by supply and demand in the marketplace and can fluctuate considerably. As an owner of mineral and royalty interests, we have no working interest or operational control over the volumes and methods of sale of the oil, natural gas, and NGL produced and sold from our properties. We do not explore, develop, or operate the properties and, accordingly, do not incur any of the associated costs.

 

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Oil, natural gas, and NGL revenues from our mineral and royalty interests are recognized when control transfers at the wellhead.

Water sales are recognized when control of the water is transferred to an E&P operator and collectability is reasonably assured.

The Partnership also earns revenue related to lease bonuses. The Partnership earns lease bonus revenue by leasing its mineral interests to E&P companies. The Partnership recognizes lease bonus revenue when the lease agreement has been executed and payment is determined to be collectible.

See Note 3 for additional disclosures regarding revenue recognition.

Concentration of Revenue

Collectability of the Partnership’s royalty revenue is dependent upon the financial condition of the Partnership’s operators as well as general economic conditions in the industry.

For the year ended December 31, 2021, in the Oil and Gas Producing Activities segment, revenue from Coterra Energy, Diamondback Energy, Inc, Callon Petroleum Company, and Oxy USA Inc represented approximately 12%, 11%, 11%, and 10% of total revenue, respectively. These figures are the same as total revenues due to the fact that revenues attributable to the Water Services Operations segment for the year ended December 31, 2021 were de minimis.

For the year ended December 31, 2020, in the Oil and Gas Producing Activities segment, revenue from Diamondback Energy, Inc, Cimarex Energy, and Oxy USA Inc represented approximately 15%, 12% and 10% of total revenue, respectively. These figures are the same as total revenues due to the fact that revenues attributable to the Water Services Operations segment for the year ended December 31, 2020 were de minimis.

For the year ended December 31, 2019, in the Oil and Gas Producing Activities segment, revenue from Cimarex Energy, Oxy USA Inc and PDC Energy represented approximately 16%, 10% and 10% of total revenue, respectively. In the Water Services Operations segment PDC Energy, WPX Energy, OXY USA Inc. and BTA Oil Producers represented 37%, 24%, 20% and 16% of total revenue, respectively. Combining both the Water Services Operations and Oil and Gas Producing Activities segments, Cimarex Energy, PDC Energy, and Oxy USA Inc represented approximately 15%, 12% and 11% of total revenue, respectively.

Although the Partnership is exposed to a concentration of credit risk, the Partnership does not believe the loss of any single operator would materially impact the Partnership’s operating results as crude oil, natural gas, and natural gas liquids are fungible products with well-established markets and numerous purchasers. If multiple operators were to cease making purchases at or around the same time, we believe there would be challenges initially, but there would be ample markets to handle the disruption. Additionally, recent rulings in bankruptcy cases involving the Partnership’s operators have stipulated that royalty owners must still be paid for oil, natural gas and NGLs extracted from their mineral acreage during the bankruptcy process. In light of this, the Partnership does not expect the entry of one of our operators into bankruptcy proceeding to materially affect our operating results.

Financial Instruments

The carrying amounts of financial instruments including cash and cash equivalents, accrued revenue and accounts receivable, accrued expenses, and other liabilities approximate fair value, as of December 31, 2021 and 2020 due to their short term nature.

The Revolving Credit Facility (defined in Note 7) has a recorded value that approximates its fair value as the interest rates are based on prevailing market rates.

 

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Deferred Financing Costs

Debt issuance costs incurred in connection with KMF Land’s entry into its credit facility, and subsequent amendments, are capitalized as deferred financing costs within other long-term assets and are amortized over the life of the facility. As of December 31, 2021 and 2020, KMF Land had unamortized debt issuance costs of $2.1 million and $1.0 million, respectively, in connection with its entry into the facility and subsequent amendments.

Deferred Offering Costs

The Partnership recognized a write-offs of approximately $2.4 million and $2.7 million of deferred offering costs for the years ended December 31, 2021 and 2020 related to the cancelation of an initial public offering in accordance with SAB Topic 5.A of the Securities and Exchange Commission.

Deferred Rent

The Partnership recognizes rental expense for an operating lease on a straight-line basis over the term of the lease agreement. The deferred rent liability on the Partnership’s condensed consolidated balance sheets is attributable to the difference between rental expense (recognized on a straight-line basis) and the variable lease payments over the term of the agreement. The Partnership has historically leased office space under a single operating lease. In September 2021, the Partnership entered into an agreement to lease new office space under a different operating lease. In December 2021, the Partnership entered into a sublease of its current office space with an unaffiliated third-party. In conjunction with the sublease, the Partnership recognized a non-cash loss of $536 thousand, which is recorded in General and Administrative on the Consolidated Statement of Operations.

Public Transaction Costs

General and administrative expense of $4.1 million for the year ended December 31, 2021 included $602 thousand related to the merger with Falcon Minerals Operating Partnership, LP (“Falcon”). See Note 14.

 

3.

Revenue from Contracts with Customers

Oil and natural gas sales

Oil, natural gas and NGL sales revenues are generally recognized when control of the product is transferred to the customer, the performance obligations under the terms of the contracts with customers are satisfied and collectability is reasonably assured. All of the Partnership’s oil, natural gas and NGL sales are made under contracts with customers (operators). The performance obligations for the Partnership’s contracts with customers are satisfied at a point in time when control transfers at the wellhead, at which point payment is unconditional. Accordingly, the Partnership’s contracts do not give rise to contract assets or liabilities. The Partnership typically receives payment for oil, natural gas and NGL sales within 30 to 90 days of the month of delivery after initial production from the well. Such periods can extend longer due to factors outside of our control. The Partnership’s contracts for oil, natural gas and NGL sales are standard industry contracts that include variable consideration based on the monthly index price and adjustments that may include counterparty-specific provisions related to volumes, price differentials, discounts and other adjustments and deductions.

Lease bonus and other income

The Partnership also earns revenue from lease bonuses, delay rentals, and right-of-way payments. The Partnership generates lease bonus revenue by leasing its mineral interests to E&P companies. A mineral lease agreement represents our contract with a customer and generally transfers the rights, for a specified

 

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period of time, to explore for and develop any oil, natural gas and NGL discovered, grants us a specified royalty interest in the hydrocarbons produced from the leased property, and requires that drilling and completion operations commence within a specified time period. The Partnership recognizes lease bonus revenues when the lease agreement has been executed and payment is determined to be collectible. At the time the Partnership executes the lease agreement, the lease bonus payment is delivered to the Partnership. Upon receipt of the lease bonus payment, the Partnership will release the recordable original lease documents to the customer. The Partnership also recognizes revenue from delay rentals to the extent drilling has not started within the specified period and payment has been received. Right-of-way payments are recorded by the Partnership when the agreement has been executed and payment is determined to be collectable. Payments for lease bonus and other income become unconditional upon the execution of an associated agreement. Accordingly, the Partnership’s lease bonus and other income transactions do not give rise to contract assets or liabilities.

Water sales

Historically, the Partnership earned revenue from water sales to various E&P operators located near its water supply assets. Water sales revenues are recognized when control of the water is transferred to the customer, the performance obligations under the terms of the contracts with customers are satisfied and collectability is reasonably assured. The performance obligations for the Partnership’s water sales are satisfied when control of the water is transferred to the customer, which may occur at the location of the Partnership’s water operations or at the customer’s well site. The Partnership’s water sales agreements are inherently short-term in nature and are executed on an as-needed basis with customers. The Partnership’s contracts for water sales are satisfied at the point in time when control of the water is transferred to the customer, at which point payment is unconditional. Accordingly, the Partnership’s contracts do not give rise to contract assets or liabilities.

In 2020, KMF Water entered into an agreement (the “Water Services Agreement”) with a third-party water services company under which the third party agreed to manage the Partnership’s water assets and operations. See Note 11 for additional information. In October of 2021, the agreement was terminated.

Allocation of transaction price to remaining performance obligations

Oil and natural gas sales

The Partnership’s right to royalty income does not originate until production occurs and, therefore, is not considered to exist beyond each day’s production. Therefore, there are no remaining performance obligations under any of our royalty income contracts.

Lease bonus and other income

Given that the Partnership does not recognize lease bonus or other income until an agreement has been executed, at which point its performance obligation has been satisfied, the Partnership does not record revenue for unsatisfied or partially unsatisfied performance obligations as of the end of the reporting period.

Water sales and leasing income

Given that the Partnership does not recognize water revenue until water is delivered or water leasing income until the lessee receives payment from its customer, at which point its performance obligation has been satisfied, the Partnership does not record revenue for unsatisfied or partially unsatisfied performance obligations as of the end of the reporting period.

 

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Prior-period performance obligations

The Partnership records revenue in the month production is delivered to the purchaser. As a royalty interest owner, the Partnership has limited visibility into the timing of when new wells start producing as production statements may not be received for 30 to 90 days or more after the date production is delivered. As a result, the Partnership is required to estimate the amount of production delivered to the purchaser and the price that will be received for the sale of the product. The expected sales volumes and prices for these properties are estimated and recorded within accounts receivable in the accompanying consolidated balance sheets. The difference between the Partnership’s estimates of royalty income and the actual amounts received for oil and natural gas sales are recorded in the month that the royalty payment is received from the customer. For the years ended December 31, 2021, 2020, and 2019, revenue recognized related to performance obligations satisfied in prior reporting periods was primarily attributable to production revisions by operators or amounts for which the information was not available at the time when revenue was estimated.

 

4.

Oil and Gas Properties

The Partnership has been and is engaged in the purchase of mineral rights in the Permian Basin in West Texas and southeastern New Mexico. The following is a summary of oil and natural gas properties as of December 31, 2021 and 2020 (in thousands):

 

Oil and natural gas properties:    December 31, 2021      December 31, 2020  

Unproved properties

   $ 817,873      $ 399,229  

Proved properties

     447,369        254,854  
  

 

 

    

 

 

 

Oil and natural gas properties, gross

     1,265,242        654,083  

Accumulated depletion and impairment

     (118,175      (77,857
  

 

 

    

 

 

 

Oil and natural gas properties, net

   $ 1,147,067      $ 576,226  
  

 

 

    

 

 

 

The Partnership paid mineral acquisition costs of approximately $38.5 million, $35.5 million, and $266.5 million for the years ended December 31, 2021, 2020, and 2019 respectively. Additionally, the Partnership acquired mineral and royalty interests of $572.2 million in three separate transactions in exchange for equity interests in a subsidiary of the Partnership. See Note 5 for additional information regarding these transactions. No such transactions occurred in the years ended December 31, 2020 and 2019. The Partnership paid $137 thousand related to purchase price adjustments from prior property sales for the year ended December 31, 2021. The Partnership received proceeds from the sale of mineral interests of $14.1 million and $22.0 million for the year ended December 31, 2020 and 2019.

 

5.

Acquisitions

Source Acquisition

In August 2021, KMF Land completed the acquisition of approximately 25,000 NRAs in the Midland and Delaware Basins from Source Energy Leasehold, LP and Permian Mineral Acquisitions, LP (together, “Source”). At close, subject to the terms and conditions of the transaction agreement, Source contributed its mineral and royalty interests to KMF Land and in consideration for the contribution, Kimmeridge affiliates caused DPM HoldCo to issue equity interests in DPM HoldCo to Source.

The Source acquisition was accounted for as an asset acquisition and, therefore, the acquired interests were recorded based on the fair value of the total assets acquired on the acquisition date. Based on the estimated fair values of the assets received, the Partnership recorded $183.2 million of the total consideration as unproved oil and gas property and $69.7 million as proved oil and gas property. Additionally, $3.5 million of transaction costs were capitalized related to the transaction.

 

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Rock Ridge Acquisition

In June 2021, KMF Land completed the acquisition of approximately 18,700 NRAs from Rock Ridge Royalty, LLC (“RRR”). At close, subject to the terms and conditions of the transaction agreement, RRR contributed its mineral and royalty interests to KMF Land and in consideration for the contribution, Kimmeridge affiliates caused DPM HoldCo (a subsidiary of the Partnership and the sole member of KMF Land, LLC) to issue equity interests in DPM HoldCo to RRR.

The RRR acquisition was accounted for as an asset acquisition and, therefore, the acquired interests were recorded based on the fair value of the total assets acquired on the acquisition date. Based on the estimated fair values of the assets received, the Partnership recorded $190.3 million of the total consideration as unproved oil and gas property and $68.3 million as proved oil and gas property. Additionally, $1.1 million of transaction costs were capitalized related to the transaction.

Delaware ORRIs Acquisition

In October 2020, another partnership owned and managed by Kimmeridge, (“Fund V”), acquired a 2.0% (on an 8/8ths basis) overriding royalty interest in all of Callon Petroleum Company’s (“Callon”) operated assets in the Delaware, Midland and Eagle Ford Basins, proportionately reduced to Callon’s net revenue interest (the “Chambers ORRI”).

In June 2021, KMF Land entered into a definitive agreement to acquire 84% of the Delaware Basin portion of the Chambers ORRI from Chambers Minerals, LLC, a subsidiary of Fund V (the “Chambers Acquisition”). Immediately following the consummation of the contributions of assets to KMF Land, Chambers HoldCo, LLC (the managing member of Chambers Minerals, LLC) was issued equity in DPM HoldCo. As the general partner of Fund V and the General Partner of the Partnership are affiliated, the transaction was approved by the Partnership’s Limited Partner Advisory Committee on June 3, 2021.

The Chambers Acquisition was accounted for as an asset acquisition. The Chambers Acquisition was also accounted for as a transaction between entities under common control; the controlling ownership and management of the general partner of Fund V and the general partner of the Partnership have significant overlap, including responsibility for the management, control, and direction of the business affairs of the respective partnerships. As KMF Land and Fund V are entities under common control, the Partnership recorded the acquisition utilizing the properties’ net book value. The properties acquired by KMF Land had a historical net book value to Fund V at the time of sale of approximately $60.6 million ($45.3 million was allocated to unproved property and $15.3 million was allocated to proved property). Accordingly, the $37.5 million excess of the fair value of the properties above their net book value was recorded as a decrease to partners’ capital at the date of the transaction.

DRC Acquisition

In July 2019, KMF Land entered into a Purchase and Sale Agreement and a Cooperation Agreement with Desert Royalty Company (“DRC”) pursuant to which KMF Land agreed to acquire an undivided 25% interest in DRC’s Delaware Basin oil and gas mineral and royalty interests. In January 2020, the entities executed an Amendment to the Letter Agreement and certain Special Warranty Deeds. In March 2021, a notice of KMF’s intent to pursue an initial public offering (an “IPO Notice”) was provided to DRC in accordance with the last agreement executed. Subsequent to this notice, the Partnership terminated the Letter Agreement with DRC in accordance with its terms.

Other Acquisitions

In February 2020, the Partnership acquired certain mineral and royalty interests in the Delaware Basin for $30.3 million. The Partnership funded the acquisition with capital contributions, cash flows from operations and borrowings under the KMF Revolving Credit Facility.

 

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In July 2021, the Partnership acquired certain mineral and royalty interests in the Delaware Basin for a total of $21.8 million in cash. The Partnership predominantly funded the acquisitions with capital contributions, cash flows from operations and borrowings under the KMF Revolving Credit Facility.

 

6.

Equity

Committed Capital

As of December 31, 2021, the Partnership had aggregate capital commitments (the “Committed Capital”) of $618.4 million from Limited Partners and $8.0 million from the General Partner. At December 31, 2021, approximately $29.5 million of this Committed Capital remained available to call for purposes of satisfying investment commitments, management fees, and expenses over the remaining life of the Partnership. Through December 31, 2021, the Partnership’s contributed capital as a percentage of total Committed Capital was approximately 95%.

As of December 31, 2020, the Partnership had aggregate capital commitments (the “Committed Capital”) of $618.4 million from Limited Partners and $8.0 million from the General Partner. At December 31, 2020, approximately $37.5 million of this Committed Capital remained available to call for purposes of satisfying investment commitments, management fees, and expenses over the remaining life of the Partnership. Through December 31, 2020, the Partnership’s contributed capital as a percentage of total Committed Capital was approximately 94%.

The General Partner may admit additional Subscription Limited Partners, or permit any existing Subscription Limited Partner to increase its Committed Capital, at one or more subsequent closings on or before the nine month anniversary of the Initial Closing except with respect to the Extended Closing Date and the Second Extended Closing Date. The General Partner and each Subscription Limited Partner that is admitted or that increases its Committed Capital at a Subsequent Closing shall make, at such Subsequent Closing, Capital Contributions for Investments, Management Fees, and Expenses such that such partners’ Capital Contributions included or made as of the date of the Subsequent Closing are equal to their Pro Rata Share of such amounts made by the Partnership as of the date of such Subsequent Closing. In September 2019, the Partnership had a Subsequent Closing and increased its Committed Capital to a total of $626.4 million, with $618.4 million from Limited Partners and $8.0 million from the General Partner. In September 2019, pursuant of Article III of the Partnership Agreement, a subsequent close rebalance was executed to reflect the change in partner ownership.

Allocation of Partners’ Net Profits and Losses

In accordance with the Partnership Agreement, net profit or net loss is generally allocated among the Capital Accounts of the Partners in accordance with the following distribution methodology.

Partners’ Distributions

Subject to the provisions of the Partnership Agreement, investment proceeds shall be distributed to the Partners, in proportion to each of their respective percentage interests, as follows:

First - 100% to such Limited Partner until such Limited Partner has received cumulative distributions pursuant to this clause (i) in an amount equal to all Capital Contributions of such Limited Partner (whether such Capital Contributions were made to fund Investments, utilized for the payment of Partnership Expenses, Management Fees or applied for any other purpose);

Second - 100% to such Limited Partner until the cumulative distributions to such Limited Partner represents an 8% per annum (compounded annually) internal rate of return on the Capital Contributions of such Limited Partner referred to in clause (i) above calculated from the due date specified in the applicable Payment Notice until the date of the distribution (the “Preferred Return Amount”);

 

18


Third - 50% to the General Partner and 50% to such Limited Partner until the General Partner has received distributions pursuant to this clause (iii) equal to the sum of (A) the ratio of such Limited Partner’s Capital Contribution to the total Capital Contributions of all Limited Partners multiplied by the General Partner’s aggregate Capital Contribution plus (B) 20% of the sum of (Y) the amount distributed to such Limited Partner pursuant to clause (ii) above and (Z) the amount distributed to such Limited Partner and to the General Partner with respect to such Limited Partner pursuant to this clause (iii); and;

Thereafter - 80% to such Limited Partner and, 20% to the General Partner.

Upon the final distribution of proceeds attributable to the Partnership’s investments, the General Partner, if required, must return to the Limited Partners, in proportion to their capital contributions used to fund the Partnership’s investments an aggregate amount, not to exceed the General Partner’s reallocation, to assure that the total distributions of proceeds attributable to the Partnership’s investments are made in accordance with the above formula.

In October 2021, DPM HoldCo distributed $60.9 million to its outside owners, including $8.7 million to an affiliate Kimmeridge fund. In November 2021, the Partnership made a distribution of $67.5 million to its partners, comprised of approximately $66.6 million to Limited Partners and $0.9 million to the General Partner.

 

7.

Long-Term Debt

Revolving Credit Facility

KMF Land is party to a credit agreement with a syndicate of banks led by Bank of America N.A. as Administrative Agent, Issuing Bank and Syndication Agent, and Capital One National Association and Barclays Bank PLC as Co-Documentation Agents (the “Revolving Credit Facility”).

Availability under our Revolving Credit Facility is governed by a borrowing base, which is subject to redetermination semi-annually each year. In addition, lenders holding two-thirds of the aggregate commitments may request one additional redetermination each year. The Partnership can also request one additional redetermination each year, and such other redeterminations as appropriate when significant acquisition opportunities arise. The borrowing base is subject to further adjustments for asset dispositions, material title deficiencies, certain terminations of hedge agreements and issuances of permitted additional indebtedness. Increases to the borrowing base requires unanimous approval of the lenders, while decreases only require approval of lenders holding two-thirds of the aggregate commitments at such time. The determination of the borrowing base takes into consideration the estimated value of KMF Land’s oil and gas mineral interests in accordance with the lenders’ customary practices for oil and gas loans. The Revolving Credit Facility is guaranteed by KMF Land and is collateralized by substantially all of the assets of KMF Land.

In June 2021, KMF Land and the Partnership entered into the Fourth Amendment to Credit Agreement (the “Fourth Amendment”). The Fourth Amendment, among other things, allowed for the consummation of the acquisitions described in Note 5.

In October 2021, KMF Land and DPM HoldCo entered into the Amended and Restated Credit Agreement with a syndicate of banks led by Bank of America N.A. as Administrative Agent, Issuing Bank and Syndication Agent. Pursuant to the Amended and Restated Credit Agreement, the initial borrowing base under the new facility is $150.0 million.

As of December 31, 2021, the borrowing base was $150.0 million as determined by the lenders and the outstanding balance under our Revolving Credit Facility was $134.0 million. As of December 31, 2020, the borrowing base was $75.0 million as determined by the lenders and the outstanding balance under our Revolving Credit Facility was $33.5 million.

The Revolving Credit Facility bears interest at a rate per annum equal to, at our option, the adjusted base rate or the adjusted LIBOR rate plus an applicable margin. The applicable margin is based on utilization of

 

19


our Revolving Credit Facility and ranges from (a) in the case of adjusted base rate loans, 1.500% to 2.500% and (b) in the case of adjusted LIBOR rate loans, 2.500% to 3.500%. The Partnership may elect an interest period of one, two, three, six, or if available to all lenders, twelve months. Interest is payable in arrears at the end of each interest period, but no less frequently than quarterly. A commitment fee is payable quarterly in arrears on the daily undrawn available commitments under our Revolving Credit Facility in an amount ranging from 0.375% to 0.500% based on utilization of our Revolving Credit Facility. The Revolving Credit Facility is subject to other customary fee, interest and expense reimbursement provisions.

As of December 31, 2021 and 2020, the weighted average interest rate related to our outstanding borrowings was 3.36% and 2.66%, respectively. As of December 31, 2021 and 2020, KMF Land had unamortized debt issuance costs of $2.1 million and $1.0 million, respectively, in connection with its entry into the facility and subsequent amendments. Such costs are capitalized as deferred financing costs within other long-term assets and are amortized over the life of the facility. For the years ended December 31, 2021 and 2020, we recognized $0.4 million and $0.3 million, respectively, in interest expense related to the amortization of deferred financing costs.

Our Revolving Credit Facility matures on September 26, 2024. Loans drawn under our Revolving Credit Facility may be prepaid at any time without premium or penalty (other than customary LIBOR breakage) and must be prepaid in the event that exposure exceeds the lesser of the borrowing base and the elected availability at such time. The principal amount of loans that are prepaid are required to be accompanied by accrued and unpaid interest and fees on such amounts. Loans that are prepaid may be reborrowed. In addition, the Partnership may permanently reduce or terminate in full the commitments under our Revolving Credit Facility prior to maturity. Any excess exposure resulting from such permanent reduction or termination must be prepaid. Upon the occurrence of an event of default under our Revolving Credit Facility, the administrative agent acting at the direction of the lenders holding a majority of the aggregate commitments at such time may accelerate outstanding loans and terminate all commitments under our Revolving Credit Facility, provided that such acceleration and termination occurs automatically upon the occurrence of a bankruptcy or insolvency event of default.

Our Revolving Credit Facility contains customary affirmative and negative covenants, including, without limitation, reporting obligations, restrictions on asset sales, restrictions on additional debt and lien incurrence and restrictions on making distributions (subject only to no default or borrowing base deficiency) and investments. In addition, our Revolving Credit Facility requires us to maintain (a) a current ratio of not less than 1.00 to 1.00 and (b) a ratio of total net funded debt to consolidated EBITDA of not more than 3.50 to 1.00. EBITDA for the period ending on December 31, 2021 is equal to EBITDA for the period beginning on July 1, 2021 and ending on December 31, 2021, multiplied by two. The Partnership was in compliance with the terms and covenants of the Revolving Credit Facility at December 31, 2021 and 2020.

 

8.

Fair Value Measurement

The Partnership is subject to ASC 820, Fair Value Measurements and Disclosures. ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). Inputs are used in applying the various valuation techniques and broadly refer to the assumptions that market participants use to make valuation decisions, including assumptions about risk. Inputs may include price information, volatility statistics, specific and broad credit data, liquidity statistics, and other factors. A financial instrument’s level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. However, the determination of what constitutes “observable” requires significant judgment by Management. Management considers observable data to be market data which is readily available, regularly distributed or updated, reliable and verifiable, not proprietary, and provided by independent sources that are actively involved in the relevant market. The categorization of a financial instrument within the hierarchy is based upon the pricing transparency of the instrument and does not necessarily correspond to Management’s perceived risk of that instrument.

 

20


Level 1 - Fair values are based on unadjusted quoted prices in active markets that are accessible at the measurement date of identical, unrestricted assets.

Level 2 - Fair values are based on quoted prices for markets that are not active or financial instruments for which all significant inputs are observable, either directly or indirectly.

Level 3 - Inputs that are unobservable and significant to the overall fair value measurement and include situations where there is little, if any, market activity for the asset or liability.

The Partnership’s proved oil and gas properties are assessed for impairment on a periodic basis. If the Partnership’s proved properties are determined to be impaired, the carrying basis of the properties is adjusted down to fair value. This represents a fair value measurement that would qualify as a non-recurring Level 3 fair value measurement. The fair value represents Management’s best estimate using the inputs available as of December 31, 2021 and 2020. No impairment of proved properties was recorded for the years ended December 31, 2021 and 2020.

The fair value of the Partnership’s derivative instruments (Level 2) was estimated using discounted cash flows and credit risk adjustments. As of December 31, 2021 and 2020, the Partnership did not have any derivative instruments outstanding. See Note 12 for further information on the fair value of our derivative instruments.

 

9.

Related Party Transactions

Management Fees

The Partnership has entered into a management services arrangement with Kimmeridge Energy Management Company, LLC (the “Manager”).

As compensation for services rendered in the management of the Partnership, the Partnership will pay the Manager with respect to each Limited Partner an annual management fee (“Management Fee”) computed on a daily basis from the date of the Initial Closing. Limited Partners who increased their Commitment to the Partnership at the Extended Closing Date will only be required to pay Management Fees with respect to their increased Commitment from and after the Extended Closing Date. Limited Partners who increased their Commitments on the Second Extended Closing Date will not be obligated to pay Management Fees with respect to such increased Commitments until after the Commitment Period Expiration Date. The Management Fee will be paid in quarterly installments on the first business day of each Fiscal Quarter with each installment to be equal to one-quarter of the amount that would be payable on the last day of its preceding Fiscal Quarter. Until the earlier of (A) the Commitment Period Expiration Date and (B) the date that the General Partner, any Principal or any Affiliate thereof first accrues or is paid a Management Fee, advisory fee or similar fee with respect to a Successor Fund (the earlier of the dates referred to in (A) or (B) being the “Initial Step-Down Date”), 2% per annum of such Limited Partner’s Commitment.

Beginning on the day after the Initial Step-Down Date and until the earlier of (A) termination of the Partnership pursuant to Article IX of the Partnership Agreement and (B) the sixth anniversary of the Final Closing (the earlier of the dates referred to in (A) or (B) being the “Second Step-Down Date”), 2% per annum of such Limited Partner’s pro rata share of the cost basis of all Investments held by the Partnership as of the end of the immediately preceding Fiscal Quarter less the value of Investments which have been written-off as a result of a permanent impairment.

Beginning on the day after the Second Step-Down Date and until the termination of the Partnership, 1% per annum of such Limited Partner’s pro rata share of the cost basis of all Investments held by the Partnership as of the end of the immediately preceding Fiscal Quarter less the value of Investments which have been written-off as a result of a permanent impairment.

Each quarterly installment of the Management Fee calculated with respect to each Limited Partner, shall be reduced by the Limited Partner’s pro rata percentage (based on Capital Contributions) of any application fees, closing fees, breakup fees or similar fees associated with an Investment or proposed investment and

 

21


other routine fees, received by the General Partner during the quarter. If the credited amounts exceed the quarterly Management Fee payment next due and payable, such excess shall be carried forward from quarter to quarter to reduce the Management Fee payable in future periods. For the years ended December 31, 2021, 2020, and 2019, there were no adjustments or credited amounts and the Manager earned and was paid approximately $7.5 million in Management Fees relating to management services.

Common Control Transaction

The Partnership has acquired oil and gas properties from separate limited partnerships whereby the General Partner of the Partnership and the general partner of the separate limited partnerships are affiliated. These transactions were accounted for as a reduction to partners’ capital as the affiliated entities were under common control. The following transaction was completed during the year ended December 31, 2021:

Delaware ORRIs Acquisition

In October 2020, another partnership owned and managed by Kimmeridge acquired a 2.0% (on an 8/8ths basis) overriding royalty interest in all of Callon’s operated assets in the Delaware, Midland and Eagle Ford Basins, proportionately reduced to Callon’s net revenue interest.

In June 2021, KMF Land entered into a definitive agreement to acquire 84% of the Delaware Basin portion of the Chambers ORRI from Chambers Minerals, LLC, a subsidiary of Fund V. Immediately following the consummation of the contributions of assets to KMF Land, Chambers HoldCo, LLC (the managing member of Chambers Minerals, LLC) was issued equity in DPM HoldCo. As the general partner of Fund V and the General Partner of the Partnership are affiliated, the transaction was approved by the Partnership’s Limited Partner Advisory Committee on June 3, 2021.

The Chambers Acquisition was accounted for as an asset acquisition. The Chambers Acquisition was also accounted for as a transaction between entities under common control; the controlling ownership and management of the general partner of Fund V and the general partner of the Partnership have significant overlap, including responsibility for the management, control, and direction of the business affairs of the respective partnerships. As KMF Land and Fund V are entities under common control, the Partnership recorded the acquisition utilizing the properties’ net book value. The properties acquired by KMF Land had a historical net book value to Fund V at the time of sale of approximately $60.6 million ($45.3 million was allocated to unproved property and $15.3 million was allocated to proved property). Accordingly, the $37.5 million excess of the fair value of the properties above their net book value was recorded as a decrease to partners’ capital at the date of the transaction.

Cost Reimbursements and Allocations from Affiliates

General and administrative expenses and certain capitalizable costs are not directly associated with the generation of the Partnership’s revenues and include costs such as employee compensation, office expenses and fees for professional services. These costs are allocated on a “time spent” basis, a pro rata basis, or by another manner which is designed to be fair and equitable. Some of those costs are incurred on the Partnership’s behalf and allocated to the Partnership by the Manager and its affiliates and reimbursed by the Partnership. These costs may not be indicative of costs incurred by the Partnership had such services been provided by an unaffiliated company during the period presented. We have not estimated what these costs and expenses would be if they were incurred by the Partnership on a standalone basis as such estimate would be impractical and lack precision. We believe the methodology utilized by Kimmeridge Operations and the Manager for the allocation of these costs to be reasonable.

Kimmeridge Operations Reimbursements

From time to time, the Partnership reimburses Kimmeridge Operations, LLC (“Kimmeridge Operations”), a wholly owned subsidiary of the Manager and affiliate of the Partnership, for general and administrative

 

22


expenses. As a subsidiary of the Manager, Kimmeridge Operations staff perform land and administrative services on behalf of the Partnership. For the years ended December 31, 2021, 2020, and 2019, the Partnership reimbursed Kimmeridge Operations for approximately $8.5 million, $3.8 million, and $7.3 million related to these services, respectively. As of December 31, 2021 and 2020, there were no amounts due to Kimmeridge Operations.

Kimmeridge Energy Management Company Reimbursements

From time to time, the Partnership reimburses the Manager for investments and expenses prefunded on behalf of the Partnership. For the years ended December 31, 2021, 2020, and 2019, the Partnership reimbursed the Manager for approximately $0.3 million, $0.4 million, and $1.5 million, respectively. As of December 31, 2021 and 2020, approximately $142 thousand and $55 thousand was due to the Manager, respectively.

 

10.    Commitment

and Contingencies

The Partnership leases office space under an operating lease. In September 2021, the Partnership entered into an agreement to lease new office space under a different operating lease. In December 2021, the Partnership entered into a sublease of its current office space with an unaffiliated third-party. Future minimum lease commitments under the lease at December 31, 2021 are presented below (in thousands):

 

Year

   Total  

2022

   $ 539  

2023

     600  

2024

     614  

2025

     628  

2026

     643  

Thereafter

     1,533  
  

 

 

 

Total

   $ 4,557  
  

 

 

 

Legal Proceedings

From time to time, the Partnership may be involved in various legal proceedings, lawsuits, and other claims in the ordinary course of business including proceedings related to environmental and other matters. Such matters are subject to many uncertainties, and outcomes are not predictable with assurance. Management does not believe that the resolution of these matters will have a material adverse impact on our financial condition, cash flows or results of operations.

 

11.    Lease

Income

In April 2020, KMF Water entered into the Water Services Agreement with a third-party water services company under which the third party agreed to manage the Partnership’s water assets and operations for an initial term of three months. Under the terms of the agreement, the third party is responsible for the production, marketing, and sales of water from the Partnership’s water properties, but each entity will each be entitled to fifty percent of the proceeds generated from water sales. The agreement also prescribes which entity (KMF or the third party) will be responsible for various costs under the arrangement. The initial term has been renewed for successive three-month periods and will continue to automatically renew for successive three-month terms unless terminated.

The Water Services Agreement constitutes a leasing arrangement under which the Partnership is a lessor. Under the terms of the agreement, the Partnership is not entitled to any income until the lessee has completed a water sale and received payment from its customer. The Partnership does not accrue this

 

23


contingent rental income until the lessee has received payment. Leasing income related to the Water Sales Agreement was $0.2 million and $13 thousand during the years ended December 31, 2021 and 2020. The agreement was terminated in October 2021.

 

12.

Derivative Instruments

Commodity Derivatives

KMF Land may enter into commodity derivative contracts to manage its exposure to oil and gas price volatility associated with its production. These derivatives are not entered into for trading or speculative purposes. While the use of these instruments limits the downside risk of adverse commodity price changes, their use may also limit future cash flows from favorable commodity price changes. Depending on changes in oil and gas futures markets and management’s view of underlying supply and demand trends, the Partnership may increase or decrease its derivative positions. The Partnership’s commodity derivative contracts have not been designated as hedges for accounting purposes; therefore, all gains and losses on commodity derivatives are recognized in the Partnership’s statement of operations.

In 2020, the Partnership utilized fixed price swaps and basis swaps to manage commodity price risks. The Partnership has entered into these swap contracts when management believes that favorable future sales prices for the Partnership’s production can be secured. Under fixed price swap agreements, when actual commodity prices upon settlement exceed the fixed price provided by the swap contracts, the Partnership pays the difference to the counterparty. When actual commodity prices upon settlement are less than the contractually provided fixed price, the Partnership receives the difference from the counterparty. In addition, the Company has entered into basis swap contracts in order to hedge the difference between the New York Mercantile Exchange (“NYMEX”) index price and a local index price that is representative of the price received by many of the operators in the Delaware Basin.

In October 2020, KMF Land terminated all of its outstanding oil and basis swap derivative contracts. KMF was not party to any derivative contracts as of December 31, 2021 and 2020.

The following table is a summary of derivative gains and losses, and where such values are recorded in the consolidated statements of operations for the years ended December 31, 2021, 2020 and 2019 (in thousands):

 

     Statement of
operations location
     Year ended
December 31, 2021
     Year ended
December 31, 2020
     Year ended
December 31, 2019
 

Commodity derivative losses

     Revenue      $ —        $ (2,573    $ —    

The fair value of commodity derivative instruments was determined using Level 2 inputs.

 

13.    Business

Segment Information

The Partnership has two reportable segments: Oil and Gas Producing Activities and Water Service Operations. The segments provide the chief operating decision maker (“CODM”) with a comprehensive financial view of the Partnership’s core business. The Partnership’s Management has been determined to be the CODM. The CODM assesses performance and allocates resources based on the two reportable segments.

The Oil and Gas Producing Activities segment is comprised of managing the mineral and royalty interests and related revenue streams of KMF Land. The revenue streams of this segment principally consist of royalties from oil, natural gas and NGL producing activities and revenues from lease bonus payments and easements. We are not a producer and the Partnership’s oil, natural gas, and NGL revenues are derived from a fixed percentage of the oil, natural gas and NGL produced from the acreage underlying our interests, net of post-production expenses and production taxes. The Water Service Operations segment comprises the

 

24


water supply assets and revenues of KMF Water. The revenue of this segment consists of water sales to various basin operators produced from the water supply assets of the Partnership, as well as lease income under the Water Services Agreement.

The Partnership evaluates the performance of its operating segments based on operating revenues and segment profit. Operating segments are defined as components of an enterprise for which separate financial information is evaluated regularly by the CODM in deciding how to allocate resources and assess performance. Segment profit is defined as segment revenues less operating expenses, depreciation, depletion and amortization, income taxes, and interest expense. Partnership expenses include general expenses associated with managing the Partnership and are not allocated directly to the two reportable segments.

The following table sets forth certain financial information with respect to the Partnership’s reportable segments (in thousands):

 

     For the year ended December 31, 2021  
     Oil and Gas
Producing
Activities
     Water
Service
Operations
     Partnership      Consolidated
Total
 

Revenues

   $ 120,362      $ 226      $ —        $ 120,588  

Depreciation, depletion and amortization

     40,619        287        —          40,906  

Income tax expense

     (555      —          (7      (562

Interest expense

     (1,918      —          —          (1,918

Segment income (loss)

     55,272        32        (7,834      47,470  

Total assets as of December 31, 2021

     1,195,520        3,314        4,020        1,202,854  

Capital expenditures including mineral acquisitions

     38,470        —          —          38,470  

A reconciliation of segment profit (loss) to net income is as follows:

           

Segment profit

   $ 47,470           

Interest income

     25           

Net income attributable to noncontrolling interests

     18,781           

Net income attributable to partners

     28,714           

 

     For the year ended December 31, 2020  
     Oil and Gas
Producing
Activities
     Water
Service
Operations
     Partnership      Consolidated
Total
 

Revenues

   $ 43,113      $ 13      $ —        $ 43,126  

Depreciation, depletion and amortization

     31,746        303        —          32,049  

Income tax expense

     (38      —          —          (38

Interest expense

     (2,021      —          —          (2,021

Segment loss

     (6,253      (165      (7,849      (14,267

Total assets as of December 31, 2020

     591,140        3,602        3,886        598,628  

Capital expenditures including mineral acquisitions

     35,836        —          —          35,836  

A reconciliation of segment profit (loss) to net income is as follows:

           

Segment loss

   $ (14,267         

Interest income

     53           

Net loss

     (14,214         

 

25


     For the year ended December 31, 2019  
     Oil and Gas
Producing
Activities
     Water
Service
Operations
     Partnership      Consolidated
Total
 

Revenues

   $ 56,205      $ 3,475      $ —        $ 59,680  

Depreciation, depletion and amortization

     25,730        471        —          26,201  

Income tax (expense) benefit

     (166      3        (8      (171

Interest expense

     (1,099      (10      —          (1,109

Segment profit (loss)

     19,559        537        (11,547      8,549  

Total assets as of December 31, 2019

     608,170        5,445        18,190        631,805  

Capital expenditures including mineral acquisitions

     266,942        637        —          267,579  

A reconciliation of segment profit (loss) to net income is as follows:

           

Segment profit

   $ 8,549           

Interest income

     241           

Net income

     8,790           

 

14.

Subsequent Events

Merger with Falcon Minerals

On January 11, 2022, DPM HoldCo, LLC entered into an Agreement and Plan of Merger with Falcon, pursuant to which Falcon will merge with and into DPM HoldCo, LLC, with DPM HoldCo, LLC continuing as the surviving entity in the Merger in an all-stock transaction, subject to Falcon shareholder approval.

 

15.

Supplemental Oil and Gas Information (Unaudited)

The Partnership’s oil and natural gas reserves are attributable solely to properties within the United States.

Capitalized oil and natural gas costs

Aggregate capitalized costs related to oil and natural gas production activities with applicable accumulated depreciation, depletion and amortization are as follows (in thousands):

 

     December 31, 2021      December 31, 2020  

Oil and natural gas interests:

     

Unproved

   $ 817,873      $ 399,229  

Proved

     447,369        254,854  
  

 

 

    

 

 

 

Total oil and natural gas interests

     1,265,242        654,083  

Accumulated depletion and impairment

     (118,175      (77,857
  

 

 

    

 

 

 

Net oil and natural gas interests capitalized

   $ 1,147,067      $ 576,226  
  

 

 

    

 

 

 

 

26


Costs incurred in oil and natural gas activities

Costs incurred in oil and natural gas property acquisition, exploration and development activities are as follows (in thousands):

 

     December 31, 2021      December 31, 2020      December 31, 2019  

Acquisition costs

        

Unproved properties

   $ 20,192      $ 21,840      $ 220,992  

Proved properties

     18,278        13,703        45,546  
  

 

 

    

 

 

    

 

 

 

Total

   $ 38,470      $ 35,543      $ 266,538  
  

 

 

    

 

 

    

 

 

 

Results of Operations from Oil and Natural Gas Producing Activities

The following schedule sets forth the revenues and expenses related to the production and sale of oil and natural gas (in thousands). It does not include any interest costs or general and administrative costs and, therefore, is not necessarily indicative of the net operating results of the Partnership’s oil, natural gas and NGL operations.

 

     December 31, 2021      December 31, 2020      December 31, 2019  

Oil, natural gas and natural gas liquids revenues

   $ 118,548      $ 44,194      $ 50,886  

Severance and ad valorem taxes

     (6,858      (3,147      (3,774

Depletion

     (40,318      (31,440      (25,684

Impairment of oil and natural gas properties

     —          (812      —    

Income tax expense

     (562      (38      (171
  

 

 

    

 

 

    

 

 

 

Results of operations from oil, natural gas and natural gas liquids

   $ 70,810      $ 8,757      $ 21,257  
  

 

 

    

 

 

    

 

 

 

The reserves at December 31, 2021, 2020, and 2019 presented below were prepared by Cawley, Gillespie & Associates, Inc. (“CGA”), independent petroleum engineers. Estimates of proved reserves are inherently imprecise and are continually subject to revision based on production history, results of additional exploration and development, price changes and other factors. The reserves are located in Texas and New Mexico.

Guidelines prescribed in FASB ASC Topic 932 Extractive Industries – Oil and Gas (“ASC Topic 932”) have been followed for computing a standardized measure of future net cash flows and changes therein related to estimated proved reserves. Future cash inflows and future production costs are determined by applying prices and costs, including transportation, quality, and basis differentials, to the period-end estimated quantities of oil, natural gas and NGL to be produced in the future. The resulting future net cash flows are reduced to present value amounts by applying a ten percent annual discount factor. Future ad valorem taxes are determined based on estimates of expenditures to be incurred in producing the proved oil and gas reserves in place at the end of the period using period-end costs and assuming continuation of existing economic conditions.

The assumptions used to compute the standardized measure are those prescribed by the FASB and the SEC. These assumptions do not necessarily reflect management’s expectations of actual revenues to be derived from those reserves, nor their present value. The limitations inherent in the reserve quantity estimation process, as discussed previously, are equally applicable to the standardized measure computations since these reserve quantity estimates are the basis for the valuation process. Reserve estimates are inherently

 

27


imprecise and estimates of new discoveries and undeveloped locations are more imprecise than estimates of established proved producing oil and gas properties. Accordingly, these estimates are expected to change as future information becomes available.

Analysis of Changes in Proved Reserves

The following table sets forth information regarding the Partnership’s net ownership interest in estimated quantities of proved developed and undeveloped oil and natural gas quantities and the changes therein for each of the periods presented:

 

     Oil
(MBbls)
    Natural Gas
(MMcf)
    Natural Gas Liquids
(MBbls)
    Total
(MBOE)
 

Balance, December 31, 2018

     3,676       16,191       1,988       8,363  

Revisions

     (438     934       (22     (305

Extensions

     1,929       6,214       704       3,668  

Acquisition of Reserves

     1,655       4,904       555       3,028  

Divestiture of Reserves

     (167     (513     (58     (310

Production

     (816     (3,237     (393     (1,749
  

 

 

   

 

 

   

 

 

   

 

 

 

Balance as of December 31, 2019

     5,839       24,493       2,774       12,695  

Revisions

     (1,098     (867     65       (1,178

Extensions

     995       3,486       423       1,999  

Acquisition of Reserves

     445       633       77       628  

Divestiture of Reserves

     (173     (209     (26     (234

Production

     (933     (4,134     (488     (2,110
  

 

 

   

 

 

   

 

 

   

 

 

 

Balance as of December 31, 2020

     5,075       23,402       2,825       11,800  

Revisions

     180       6,531       405       1,674  

Extensions

     610       1,991       216       1,158  

Acquisition of Reserves

     7,240       19,165       2,076       12,511  

Production

     (1,261     (4,746     (499     (2,551
  

 

 

   

 

 

   

 

 

   

 

 

 

Balance as of December 31, 2021

     11,844       46,343       5,023       24,592  
  

 

 

   

 

 

   

 

 

   

 

 

 

 

Proved developed and undeveloped reserves:    Oil
(MBbls)
     Natural Gas
(MMcf)
     Natural Gas Liquids
(MBbls)
     Total
(MBOE)
 

Developed as of December 31, 2018

     2,541        12,840        1,576        6,259  

Undeveloped as of December 31, 2018

     1,135        3,351        412        2,104  
  

 

 

    

 

 

    

 

 

    

 

 

 

Balance at December 31, 2018

     3,676        16,191        1,988        8,363  
  

 

 

    

 

 

    

 

 

    

 

 

 

Developed as of December 31, 2019

     4,223        20,293        2,298        9,903  

Undeveloped as of December 31, 2019

     1,616        4,200        476        2,792  
  

 

 

    

 

 

    

 

 

    

 

 

 

Balance at December 31, 2019

     5,839        24,493        2,774        12,695  
  

 

 

    

 

 

    

 

 

    

 

 

 

Developed as of December 31, 2020

     3,731        19,505        2,352        9,334  

Undeveloped as of December 31, 2020

     1,344        3,897        473        2,466  
  

 

 

    

 

 

    

 

 

    

 

 

 

Balance at December 31, 2020

     5,075        23,402        2,825        11,800  
  

 

 

    

 

 

    

 

 

    

 

 

 

Developed as of December 31, 2021

     9,285        40,747        4,417        20,494  

Undeveloped as of December 31, 2021

     2,559        5,596        606        4,098  
  

 

 

    

 

 

    

 

 

    

 

 

 

Balance at December 31, 2021

     11,844        46,343        5,023        24,592  
  

 

 

    

 

 

    

 

 

    

 

 

 

For the year ended December 31, 2021, the Partnership had upward revisions of 180 MBbls of oil and 6,531 MMcf of gas and 405 MBbls of NGL. Total upward revisions of 1,674 MBOE were primarily due to

 

28


upward revisions of 1,184 MBOE related to changes in estimated ultimate recovery and upward revisions of 490 MBOE due to increases in pricing. For the year ended December 31, 2021, the Partnership had extensions of 610 MBbls of oil, 1,991 MMcf of gas, and 216 MBbls of NGLs of which 289 MBbls of oil, 883 MMcf of gas, and 96 MBbls of NGLs were from conversions of non-proved resources to proved developed producing and proved developed not producing due to operator drilling activity and 321 MBbls of oil, 1,108 MMcf of gas, and 120 MBbls of NGLs were from additional proved undeveloped reserves. In 2021, the Partnership acquired royalty and mineral interests of 7,240 MBbls of oil, 19,165 MMcf of gas, and 2,076 MBbls of NGLs through multiple acquisitions. For the year ended December 31, 2021, the Partnership did not divest any royalty and mineral interests.

For the year ended December 31, 2020, the Partnership had downward revisions of 1,098 MBbls of oil and 867 MMcf of gas and upward revisions of 65 MBbls of NGL. Total downward revisions of 1,178 MBOE were primarily due to downward revisions of 887 MBOE related to changes in estimated ultimate recovery and downward revisions of 239 MBOE due to decreases in pricing. For the year ended December 31, 2020, the Partnership had extensions of 995 MBbls of oil, 3,486 MMcf of gas, and 423 MBbls of NGLs of which 192 MBbls of oil, 672 MMcf of gas, and 81 MBbls of NGLs were from conversions of non-proved resources to proved developed producing due to operator drilling activity and 803 MBbls of oil, 2,814 MMcf of gas, and 342 MBbls of NGLs were from additional proved undeveloped reserves. In 2020, the Partnership acquired royalty and mineral interests of 445 MBbls of oil, 633 MMcf of gas, and 77 MBbls of NGLs through multiple acquisitions. For the year ended December 31, 2020, the Partnership divested royalty and mineral interests of 173 MBbls, 209 MMcf, and 26 MBbls of proved oil, natural gas, and NGL, respectively, in conjunction with the conveyances to DRC described in Note 5.

For the year ended December 31, 2019, the Partnership had downward revisions of 13 MBbls of oil, 34 MMcf of gas and 4 MBbls of NGL due to the removal of 11 wells that were no longer economically feasible. Additional downward revisions of 425 MBbls of oil and 18 MBbls of NGLs were largely due to decreases in pricing. Decreases in gas pricing were offset by positive performance revisions, resulting in an upward revision of 968 MMcf of gas. For the year ended December 31, 2019, the Partnership had extensions of 1,929 MBbls of oil, 6,214 MMcf of gas, and 704 MBbls of NGLs of which 837 MBbls of oil, 3,234 MMcf of gas, and 367 MBbls of NGLs were from conversions of non-proved resources to proved developed producing due to operator drilling activity and 1,092 MBbls of oil, 2,980 MMcf of gas, and 337 MBbls of NGLs were from additional proved undeveloped reserves. In 2019, the Partnership acquired royalty and mineral interests of 1,655 MBbls of oil, 4,904 MMcf of gas and 555 MBbls of NGLs through multiple acquisitions including the acquisition of DRC described in Note 5. For the year ended December 31, 2019, the Partnership divested royalty and mineral interests of 167 MBbls, 513 MMcf, and 58 MBbls of proved oil, gas and NGL, respectively, in conjunction with the conveyances to DRC described in Note 5.

Standardized Measure of Oil and Gas

The standardized measure of discounted future net cash flows is based on the unweighted average, first-day-of-the-month price. The projections should not be viewed as realistic estimates of future cash flows, nor should the “standardized measure” be interpreted as representing current value to the Partnership. Material revisions to estimates of proved reserves may occur in the future; development and production of the reserves may not occur in the periods assumed; actual prices realized are expected to vary significantly from those used; and actual costs may vary. Our calculations of the standardized measure of discounted future net cash flows and the related changes therein include Texas margin tax and do not include the effect of estimated federal income tax expenses because the Partnership is not subject to federal income taxes.

As of December 31, 2021, the reserves are comprised of 48% crude oil, 32% natural gas and 20% NGL on an energy equivalent basis.

For the years ended December 31, 2021, 2020, and 2019, future cash inflows are calculated by applying the 12-month arithmetic average of the first-of-month price from January to December, of oil and gas relating to

 

29


the Partnership’s proved reserves, to the year-end quantities of those reserves. The values for the December 31, 2021, 2020, and 2019 proved reserves were derived based on prices presented in the table below. The crude oil pricing was based on the West Texas Intermediate (“WTI”) price; the NGL pricing was 45% of WTI for 2021, 28% of WTI for 2020 and 27% of WTI for 2019; the natural gas pricing was based on the Henry Hub price. All prices have been adjusted for transportation, quality and basis differentials.

 

     Oil
(Bbl)
     Natural Gas
(Mcf)
     NGL
(Bbl)
 

December 31, 2021 (Average)

   $ 64.33      $ 3.35      $ 30.14  

December 31, 2020 (Average)

   $ 36.28      $ 1.02      $ 11.01  

December 31, 2019 (Average)

   $ 50.92      $ 0.69      $ 14.90  

The standardized measure of discounted future net cash flows are based on the average market prices for sales of oil, natural gas and NGL adjusted for basis differentials, on the first-day-of-the-month price. The projections should not be viewed as realistic estimates of future cash flows, nor should the “standardized measure” be interpreted as representing current value to the Partnership. Material revisions to estimates of proved reserves may occur in the future; development and production of the reserves may not occur in the periods assumed; actual prices realized are expected to vary significantly from those used; and actual costs may vary.

The following summary sets forth the future net cash flows related to proved oil and gas reserves based on the standardized measure prescribed in ASC Topic 932 (in thousands):

 

     Year Ended December 31,  
     2021      2020      2019  

Future oil and natural gas sales

   $ 1,068,652      $ 238,977      $ 355,551  

Future production costs

     (90,137      (19,379      (28,178

Future income tax expense (1)

     (5,302      (1,236      (1,852
  

 

 

    

 

 

    

 

 

 

Future net cash flows

     973,213        218,362        325,521  
  

 

 

    

 

 

    

 

 

 

10% annual discount

     (437,910      (94,803      (142,296
  

 

 

    

 

 

    

 

 

 

Standardized measure of discounted future net cash flows

   $ 535,303      $ 123,559      $ 183,225  
  

 

 

    

 

 

    

 

 

 

The principal sources of change in the standardized measure of discounted future net cash flows are (in thousands):

 

     Year Ended December 31,  
     2021      2020      2019  

Balance at the beginning of the period

   $ 123,559      $ 183,225      $ 155,432  

Net change in prices and production costs

     119,993        (59,911      (38,177

Sales, net of production costs

     (111,691      (41,043      (47,112

Extensions and discoveries

     29,853        25,196        53,246  

Acquisitions of reserves

     326,192        9,137        43,946  

Divestiture of reserves

     —          (3,563      (5,795

Revisions of previous quantity estimates

     43,843        (18,140      (6,414

Net change in income taxes (1)

     (2,205      343        (150

Accretion of discount

     12,426        18,427        15,632  

Changes in timing and other

     (6,667      9,888        12,617  
  

 

 

    

 

 

    

 

 

 

Balance at the end of the period

   $ 535,303      $ 123,559      $ 183,225  
  

 

 

    

 

 

    

 

 

 

 

30


(1)

The Company was not subject to U.S. federal income taxes for the years ended December 31, 2021, 2020, and 2019. Accordingly, no provision for income taxes has been provided in the Consolidated Statement of Operations. If the Company had been subject to entity-level income taxation, the unaudited pro forma future income tax expense at December 31, 2021, 2020, and 2019 would have been $3.8 million, $6.9 million, and $24.7 million, respectively. The unaudited pro forma standardized measure of discounted future net cash flows at December 31, 2021, 2020, and 2019 would have been $534.4 million, $120.0 million, and $169.8 million, respectively.

 

31

Exhibit 99.4

KIMMERIDGE MINERAL FUND, LP AND SUBSIDIARIES

CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

MARCH 31, 2022 AND 2021


KIMMERIDGE MINERAL FUND, LP

CONTENTS

 

Financial Statements

  

CONDENSED CONSOLIDATED BALANCE SHEETS

     F-1  

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

     F-2  

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

     F-3  

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

     F-4  

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

     5-21  


KIMMERIDGE MINERAL FUND, LP

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands)

(Unaudited)

 

     MARCH 31,
2022
    DECEMBER 31,
2021
 

ASSETS

    

Current assets

    

Cash and cash equivalents

   $ 13,585     $ 12,379  

Accrued revenue and accounts receivable, net

     48,488       36,202  

Prepaid assets

     345       235  
  

 

 

   

 

 

 

Total current assets

     62,418       48,816  
  

 

 

   

 

 

 

Property and equipment

    

Oil and natural gas properties, successful efforts method:

    

Unproved properties

     795,736       817,873  

Proved properties

     470,002       447,369  

Other property and equipment

     8,424       8,187  

Accumulated depreciation, depletion and amortization

     (136,921     (121,536
  

 

 

   

 

 

 

Net oil and gas properties and other property and equipment

     1,137,241       1,151,893  
  

 

 

   

 

 

 

Other long-term assets

    

Deposits for property acquisition

     2,700       —    

Deferred financing costs

     2,226       2,145  
  

 

 

   

 

 

 

Total other long-term assets

     4,926       2,145  
  

 

 

   

 

 

 

TOTAL ASSETS

   $ 1,204,585     $ 1,202,854  
  

 

 

   

 

 

 

LIABILITIES AND EQUITY

    

Current liabilities

    

Accrued expenses and other liabilities

   $ 6,538     $ 4,140  

Due to affiliates (Note 10)

     121       442  

Derivative liabilities

     468       —    
  

 

 

   

 

 

 

Total current liabilities

     7,127       4,582  
  

 

 

   

 

 

 

Long-term liabilities

    

Long-term debt

     94,000       134,000  

Deferred rent

     1,147       1,129  

Long-term derivative liabilities

     646       —    
  

 

 

   

 

 

 

Total long-term liabilities

     95,793       135,129  
  

 

 

   

 

 

 

Total liabilities

     102,920       139,711  
  

 

 

   

 

 

 

COMMITMENTS AND CONTINGENCIES (NOTE 11)

    

Equity

    

Partners’ capital

     579,902       560,622  

Noncontrolling interests

     521,763       502,521  
  

 

 

   

 

 

 

Total equity

     1,101,665       1,063,143  

TOTAL LIABILITIES AND EQUITY

   $ 1,204,585     $ 1,202,854  
  

 

 

   

 

 

 

 

F-1


KIMMERIDGE MINERAL FUND, LP

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(In thousands)

(Unaudited)

 

     THREE MONTHS ENDED
MARCH 31,
 
     2022     2021  

Revenue:

    

Oil, natural gas and natural gas liquids revenues

   $ 64,951     $ 16,453  

Lease bonus and other income

     1,412       596  
  

 

 

   

 

 

 

Total revenues

     66,363       17,049  
  

 

 

   

 

 

 

Operating expenses:

    

Management fees to affiliates (Note 10)

     1,870       1,870  

Depreciation, depletion and amortization

     15,385       6,865  

General and administrative

     3,983       703  

General and administrative—affiliates (Note 10)

     80       1,638  

Severance and ad valorem taxes

     3,725       1,110  
  

 

 

   

 

 

 

Total operating expenses

     25,043       12,186  
  

 

 

   

 

 

 

Net income from operations

     41,320       4,863  

Other expense:

    

Interest expense, net

     (1,168     (306

Commodity derivatives losses

     (1,114     —    
  

 

 

   

 

 

 

Income before income tax expense

     39,038       4,557  

Income tax expense

     (516     (81
  

 

 

   

 

 

 

Net income including noncontrolling interests

     38,522       4,476  

Net income attributable to noncontrolling interests

     19,242       —    
  

 

 

   

 

 

 

Net income attributable to partners

   $ 19,280     $ 4,476  
  

 

 

   

 

 

 

 

F-2


KIMMERIDGE MINERAL FUND, LP

CONDENSED CONSOLIDATED STATEMENTS OF CHANGE IN EQUITY

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(In thousands)

(Unaudited)

 

     General Partner      Limited Partners      Noncontrolling
interests
     Total Equity  

Equity at January 1, 2021

   $ 7,326      $ 555,071      $ —        $ 562,397  

Net income

     81        4,395        —          4,476  
  

 

 

    

 

 

    

 

 

    

 

 

 

Equity at March 31, 2021

   $ 7,407      $ 559,466      $ —        $ 566,873  
  

 

 

    

 

 

    

 

 

    

 

 

 

Equity at January 1, 2022

   $ 7,375      $ 553,247      $ 502,521      $ 1,063,143  

Net income

     270        19,010        19,242        38,522  
  

 

 

    

 

 

    

 

 

    

 

 

 

Equity at March 31, 2022

   $ 7,645      $ 572,257      $ 521,763      $ 1,101,665  
  

 

 

    

 

 

    

 

 

    

 

 

 

 

F-3


KIMMERIDGE MINERAL FUND, LP

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)

 

     THREE MONTHS ENDED
MARCH 31,
 
     2022     2021  

Cash flows from operating activities:

    

Net income attributable to partners including noncontrolling interests

   $ 38,522     $ 4,476  

Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:

    

Depreciation, depletion and amortization

     15,385       6,865  

Commodity derivative losses

     1,114       —    

Change in operating assets and liabilities:

    

Accrued revenue and accounts receivable, net

     (12,286     (1,918

Other prepaid assets

     (110     (63

Deferred financing costs

     204       67  

Accrued expenses and other liabilities

     2,099       (664

Due to affiliates (Note 10)

     (343     742  

Deferred rent

     18       (11
  

 

 

   

 

 

 

Net cash provided by operating activities

     44,603       9,494  
  

 

 

   

 

 

 

Cash flows from investing activities:

    

Purchases of oil and gas properties

     (461     105  

Proceeds from sales of oil and gas properties

     —         (54

Purchases of other property and equipment

     (215     —    

Deposits for property acquisitions

     (2,700     —    
  

 

 

   

 

 

 

Net cash provided by (used) in investing activities

     (3,376     51  
  

 

 

   

 

 

 

Cash flows from financing activities:

    

Repayments on credit facility

     (40,000     (8,500

Payments of deferred financing costs

     (11     (26

Deferred initial public offering costs

     (10     —    
  

 

 

   

 

 

 

Net cash used in financing activities

     (40,021     (8,526
  

 

 

   

 

 

 

Net change in cash and cash equivalents

     1,206       1,019  

Cash and cash equivalents, beginning of year

     12,379       7,531  
  

 

 

   

 

 

 

Cash and cash equivalents, end of period

   $ 13,585     $ 8,550  
  

 

 

   

 

 

 

Supplemental disclosure of non-cash transactions:

    

Increase in current liabilities for additions to property and equipment

   $ 36     $ —    

Supplemental disclosure of cash flow information:

    

Cash paid for income taxes

   $ 178     $ 16  

Cash paid for interest expense:

     1,047       255  

 

F-4


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

1.

Organization

Kimmeridge Mineral Fund, LP and Subsidiaries (the “Partnership”) is a Delaware limited partnership operating under the Third Amendment to the Second Amended and Restated Limited Partnership Agreement (the “Partnership Agreement”) dated as of July 19, 2019. The Partnership formed on November 1, 2016 and commenced operation on November 11, 2016. The primary purpose of the Partnership is to acquire, own and manage mineral and royalty interests in the Permian Basin, located in West Texas and southeastern New Mexico of the United States. Mineral interests are real property interests that are typically perpetual and grant ownership of the oil and natural gas underlying a tract of land and the rights to explore for, drill for, and produce oil and natural gas on that land or to lease those exploration and development rights to a third party. When those rights are leased to third party operators, usually for a one to three-year term, the Partnership typically receives an upfront cash payment, known as a lease bonus, and the Partnership retains a mineral royalty, which entitles the Partnership to a cost-free percentage (up to 25%) of production or revenue from production free of lease operating expenses. The Partnership also owns surface rights which generate revenues from the sale of water produced from the Partnership’s water supply assets and from rights-of-way, easements and other rights.

The Partnership Agreement provides that the Partnership will continue (unless earlier dissolved) for ten years from the final closing date provided, however, that Kimmeridge Mineral GP, LLC (the “General Partner” or “Management”), may, in its discretion, extend the term of the Partnership for two additional one-year periods. In addition, the General Partner may extend the term of the Partnership for a third additional three-year period (the “Final Extension”); provided however, that the General Partner shall provide notice of such a proposed extension to the Limited Partners at least 60 calendar days before the expiration of the then current term. The Final Extension shall automatically take effect unless a majority of the Limited Partnership Advisory Committee (“LPAC”) members notify the General Partner in writing within 30 calendar days of receipt of the extension notice of their decision not to allow the Final Extension. Except as may be required by law or expressly provided for in the Partnership Agreement, the liability of each Limited Partner is limited to its Capital Commitment.

 

2.

Basis of Presentation and Summary of Significant Accounting Policies

Basis of Presentation

These condensed consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (“GAAP”). In the opinion of management, the accompanying condensed consolidated financial statements include all adjustments (consisting of normal and recurring accruals) considered necessary to present fairly the Partnership’s financial position as of March 31, 2022 and December 31, 2021, and the results of its operations and its cash flows for the three months ended March 31, 2022 and 2021. The Partnership has no items of other comprehensive income or loss; therefore, its net income or loss is equal to its comprehensive income or loss.

Use of Estimates

The preparation of condensed consolidated financial statements in conformity with GAAP requires Management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the condensed consolidated financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates.

The Partnership’s estimates and classification of oil and natural gas reserves are, by necessity, projections based on geologic and engineering data, and there are uncertainties inherent in the interpretation of such data as well as the projection of future rates of production. Reserve engineering is a subjective process of estimating underground accumulations of oil and natural gas that are difficult to measure. The accuracy of any reserve estimate is a function of the quality of available data, engineering, and geological interpretation and judgment. Estimates of economically recoverable oil and natural gas reserves and future net cash flows necessarily depend upon a number of variable factors and assumptions. These factors and assumptions include historical production from the area compared with production from other producing areas, the assumed effect of regulations by governmental agencies, and assumptions governing future oil and natural gas prices. For these reasons, estimates of the economically recoverable quantities of expected oil and natural gas and estimates of the future net cash flows may vary substantially.

 

F-5


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

Any significant variance in the assumptions could materially affect the estimated quantity of reserves, which could affect the carrying value of the Partnership’s oil and natural gas properties and/or the rate of depletion related to oil and natural gas properties.

Principles of Consolidation

The accompanying condensed consolidated financial statements include the accounts of the Partnership’s wholly-owned subsidiaries and any entities in which the Partnership owns a controlling interest. All intercompany accounts and transactions have been eliminated in consolidation. Noncontrolling interests in the Partnership’s condensed consolidated financial statements represents the interests in a subsidiary of the Partnership, DPM HoldCo, LLC (“DPM HoldCo”), which are owned by outside parties. Noncontrolling interests in consolidated subsidiaries is included as a component of equity in the Partnership’s condensed consolidated balance sheets.

Risks and Uncertainties

The ongoing global spread of the novel coronavirus (“COVID-19”), has caused a continuing disruption to the oil and natural gas industry and to our business by, among other things, contributing to a significant decrease in global crude oil demand and the price for oil in 2020. This disruption has been somewhat alleviated in 2022. However, the current price environment remains uncertain as responses to the COVID-19 pandemic and newly emerging variants of the virus continue to evolve. Additionally, significant geopolitical events may cause increased volatility in the price of oil and natural gas.

The markets for oil, natural gas and natural gas liquids (“NGL”) have experienced significant price fluctuations. Such price volatility is expected to continue into the future. Lower commodity prices may reduce the amount of oil, natural gas and NGL that can be produced economically by operators. Increases or decreases in commodity prices could impact the Partnership’s financial performance and expected operating results, which may include future reserves estimates and potential recognition of impairment charges related to the Partnership’s mineral and royalty interests.

Recent Accounting Pronouncements

In February 2016, the FASB issued ASU 2016-02, Leases, which requires all leasing arrangements to be presented on the balance sheet as liabilities along with a corresponding asset. ASU 2016-02 does not apply to leases of mineral rights to explore for or use crude oil and natural gas. The ASU will replace most existing lease guidance in GAAP when it becomes effective. In January 2018, the FASB issued ASU 2018-01, Land Easement Practical Expedient for Transition to Topic 842, to provide an optional practical expedient to not evaluate existing or expired land easements that were not previously accounted for as leases under Topic 840. In July 2018, the FASB issued ASU 2018-11 Leases: Targeted Improvements, which provides for another transition method, in addition to the existing transition method, by allowing entities to initially apply the new leases standard at the adoption date and recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption (i.e. comparative periods presented in the financial statements will continue to be in accordance with current GAAP (Topic 840, Leases)). The new standards become effective for the Partnership during the fiscal year ending December 31, 2022 and interim periods within the fiscal year ending December 31, 2023. Early adoption is permitted. We are currently evaluating the impact that the adoption of this standard will have on our financial statements, but believe the primary effect of adoption will be to record right-of-use assets and lease liabilities for office leases currently accounted for as operating leases under Topic 840.

In June 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses, which amends current impairment guidance by adding an impairment model (known as the current expected credit loss model (“CECL”) that is based on expected losses rather than incurred losses. Under the new guidance, an entity recognizes as an allowance its estimate of lifetime expected credit losses, which the FASB believes will result in more timely recognition of such losses. ASU 2016-13 is effective for annual periods beginning after December 15, 2022 and interim periods within those annual periods. The Partnership is currently evaluating the impact of the adoption of this standard but does not believe it will have a material impact on the Partnership’s financial statements.

In March 2020, the FASB issued ASU 2020-04, Facilitation of the Effects of Reference Rate Reform on Financial Reporting. In response to the cessation of the London Interbank Offered Rate (“LIBOR”) by December 31, 2021, the FASB issued this update to provide optional expedients and exceptions for applying GAAP to contract modifications, hedging relations, and other affected transactions. The Partnership currently only has one contract subject to LIBOR, its revolving

 

F-6


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

credit facility, that may be impacted by this ASU. Modifications of debt contracts should be accounted for by prospectively adjusting the effective interest rate. This update is effective immediately, but may be adopted through December 31, 2022, and allows for elections to be made by the Partnership in terms of how the ASU is adopted. Once elected for a Topic or Industry Subtopic, the update must be applied prospectively for all eligible contract modifications. The Partnership is currently evaluating the impact of the adoption of this standard but does not believe it will have a material impact on the Partnership’s financial statements.

Cash and Cash Equivalents

The Partnership considers all highly-liquid instruments purchased with an original maturity of three months or less to be cash equivalents. The Partnership maintains cash and cash equivalents in bank deposit accounts which, at times, may exceed the federally insured limits. The Partnership has not experienced any significant losses from such investments.

Accrued Revenue and Accounts Receivable

Accrued revenue and accounts receivable represent amounts due to the Partnership and are uncollateralized, consisting primarily of royalty revenue receivable. Royalty revenue receivable consists of royalties due from operators for oil, natural gas and NGL volumes sold to purchasers. Those purchasers remit payment for production to the operator of the properties and the operator, in turn, remits payment to the Partnership. Receivables from third parties for which we did not receive actual production information, either due to timing delays or due to the unavailability of data at the time when revenues are recognized, are estimated.

The Partnership routinely assesses the recoverability of all material accounts receivable to determine their collectability. The Partnership accrues a reserve to the allowance for doubtful accounts when it is probable that a receivable will not be collected and the amount of the reserve may be reasonably estimated. The Partnership had an allowance for doubtful accounts related to its KMF Water, LLC (“KMF Water”) receivables of $0.2 million and $0.2 million as of March 31, 2022 and December 31, 2021, respectively. There were no such allowances for KMF Land LLC’s (“KMF Land”) royalty revenue receivables as of March 31, 2022 and December 31, 2021.

Oil and Gas Properties

The Partnership uses the successful efforts method of accounting for oil and natural gas producing properties, as further defined under ASC 932, Extractive Activities—Oil and Natural Gas. Under this method, costs to acquire mineral interests in oil and natural gas properties are capitalized. The costs of non-producing mineral interests and associated acquisition costs are capitalized as unproved properties pending the results of leasing efforts and drilling activities of Exploration and Production (“E&P”) operators on our interests. As unproved properties are determined to have proved reserves, the related costs are transferred to proved oil and gas properties. Capitalized costs for proved oil and natural gas mineral interests are depleted on a unit-of-production basis over total proved reserves. For depletion of proved oil and gas properties, interests are grouped in a reasonable aggregation of properties with common geological structural features or stratigraphic conditions. Depletion expense totaled approximately $15.2 million and $6.7 million for the three months ended March 31, 2022 and 2021, respectively.

Other Property and Equipment

Other property and equipment is recorded at cost, which includes water supply assets (water wells and water storage pits), and leasehold improvements. Depreciation and amortization are calculated using the straight-line method over the estimated useful lives of the assets. Leasehold improvements are depreciated over the shorter of the lease term or the useful lives of the assets. The Partnership recorded approximately $147 thousand and $147 thousand in depreciation for water assets and other property and equipment for the three months ended March 31, 2022 and 2021.

The costs to drill water wells are capitalized while drilling is in progress. If a water well is determined to be unsuccessful or unproductive prior to being placed in service, the associated costs will be charged to expense in the period the determination is made. No expense was recognized in connection with unsuccessful water wells for the three months ended March 31, 2022 and 2021. Additionally, we evaluate our other property and equipment for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset that has been placed in service may not be recoverable. No impairment charge was recorded for the three months ended March 31, 2022 and 2021.

 

F-7


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

Impairment of Oil and Gas Properties

The Partnership evaluates its producing properties for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. When assessing proved properties for impairment, the Partnership compares the expected undiscounted future cash flows of the proved properties to the carrying amount of the proved properties to determine recoverability. If the carrying amount of proved properties exceeds the expected undiscounted future cash flows, the carrying amount is written down to the properties’ estimated fair value, which is measured as the present value of the expected future cash flows of such properties. The factors used to determine fair value include estimates of proved reserves, future commodity prices, timing of future production, and a risk-adjusted discount rate. There was no impairment of proved properties for the three months ended March 31, 2022 and 2021. The proved property impairment test is primarily impacted by future commodity prices, changes in estimated reserve quantities, estimates of future production, overall proved property balances, and depletion expense. If pricing conditions decline or are depressed, or if there is a negative impact on one or more of the other components of the calculation, we may incur proved property impairments in future periods.

Unproved oil and gas properties are assessed periodically for impairment of value, and a loss is recognized at the time of impairment by charging capitalized costs to expense. Impairment is assessed based on when facts and circumstances indicate that the carrying value may not be recoverable, at which point an impairment loss is recognized to the extent the carrying value exceeds the estimated recoverable value. Factors used in the assessment include but are not limited to commodity price outlooks and current and future operator activity in the Permian Basin. The Partnership recognized no impairment of unproved properties for the three months ended March 31, 2022 and 2021.

Derivative Financial Instruments

In order to manage its exposure to oil, natural gas, and NGL price volatility, the Partnership may periodically enter into derivative transactions, which may include commodity swap agreements, basis swap agreements, and other similar agreements which help manage the price risk associated with the Partnership’s production. These derivatives are not entered into for trading or speculative purposes. To the extent legal right of offset exists with a counterparty, the Partnership reports derivative assets and liabilities on a net basis. The Partnership has exposure to credit risk to the extent that the counterparty is unable to satisfy its settlement obligations. The Partnership actively monitors the creditworthiness of the counterparty and assesses the impact, if any, on its derivative positions.

The Partnership records derivative instruments on its condensed consolidated balance sheets as either assets or liabilities measured at fair value and records changes in the fair value of derivatives in current earnings as they occur. Changes in the fair value of commodity derivatives, including gains or losses on settled derivatives, are classified as other income or loss on the Partnership’s condensed consolidated statements of income. The Partnership’s derivatives have not been designated as hedges for accounting purposes.

Accrued Expenses and Other Liabilities

The Partnership’s accrued expenses and other liabilities consisted of the following as of the dates indicated (in thousands):

 

     March 31, 2022      December 31, 2021  

General and administrative

     2,722        904  

Ad valorem taxes payable

     1,288        1,750  

Other taxes payable

     867        529  

Payable to seller for pre-effective monies

     555        104  

Capital expenditures

     427        391  

Deferred financing costs

     286        13  

Interest expense

     192        274  

Other

     201        175  
  

 

 

    

 

 

 

Total accrued expenses and other liabilities

   $ 6,538      $ 4,140  
  

 

 

    

 

 

 

 

F-8


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

Income Taxes

The Partnership is organized as a pass-through entity for income tax purposes. As a result, the partners are responsible for federal and state income taxes attributable to their share of the Partnership’s taxable income. However, the Partnership is required to pay Texas State franchise taxes and certain New Mexico income taxes. The Partnership recognized approximately $516 thousand and $81 thousand of state income taxes for the three months ended March 31, 2022 and 2021, respectively.

Revenue Recognition

Mineral and royalty interests represent the right to receive revenues from the sale of oil, natural gas and NGL, less production taxes and post-production expenses. The prices of oil, natural gas, and NGL from the properties in which we own a mineral or royalty interest are primarily determined by supply and demand in the marketplace and can fluctuate considerably. As an owner of mineral and royalty interests, we have no working interest or operational control over the volumes and methods of sale of the oil, natural gas, and NGL produced and sold from our properties. We do not explore, develop, or operate the properties and, accordingly, do not incur any of the associated costs.

Oil, natural gas, and NGL revenues from our mineral and royalty interests are recognized when control transfers at the wellhead.

The Water Services Agreement (defined in Note 3) constitutes a leasing arrangement through October 2021 under which the Partnership is a lessor. Under the terms of the agreement, the Partnership is not entitled to any income until the lessee has completed a water sale and received payment from its customer. The Partnership does not accrue this contingent rental income until the lessee has received payment.

Water sales are recognized when control of the water is transferred to an E&P operator and collectability is reasonably assured.

The Partnership also earns revenue related to lease bonuses. The Partnership earns lease bonus revenue by leasing its mineral interests to E&P companies. The Partnership recognizes lease bonus revenue when the lease agreement has been executed and payment is determined to be collectible.

See Note 3 for additional disclosures regarding revenue recognition.

Concentration of Revenue

Collectability of the Partnership’s royalty revenue is dependent upon the financial condition of the Partnership’s operators, the entities they sell their products to, as well as general economic conditions in the industry.

Although the Partnership is exposed to a concentration of credit risk, the Partnership does not believe the loss of any single operator or entity would materially impact the Partnership’s operating results as crude oil, natural gas, and NGL are fungible products with well-established markets and numerous purchasers. If multiple entities were to cease making purchases at or around the same time, we believe there would be challenges initially, but there would be ample markets to handle the disruption. Additionally, recent rulings in bankruptcy cases involving the Partnership’s operators have stipulated that royalty owners must still be paid for oil, natural gas and NGL extracted from their mineral acreage during the bankruptcy process. In light of this, the Partnership does not expect the entry of one of our operators into bankruptcy proceeding to materially affect our operating results.

Financial Instruments

The carrying amounts of financial instruments including cash and cash equivalents, accrued revenue and accounts receivable, accrued expenses, and other liabilities approximate fair value, as of March 31, 2022 and December 31, 2021 due to their short-term nature.

 

F-9


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

The fair values of the Partnership’s derivative asset and liabilities are based on a third-party industry-standard pricing model using contract terms, prices, assumptions, and inputs that are substantially observable in active markets throughout the full term of the instruments, including forward oil and gas price curves, discount rates, and credit risk adjustments. See Note 7 for information regarding the fair values of derivative instruments.

The Revolving Credit Facility (defined in Note 8) has a recorded value that approximates its fair value as the interest rates are based on prevailing market rates.

Deferred Financing Costs

Debt issuance costs incurred in connection with KMF Land’s entry into its credit facility, and subsequent amendments, are capitalized as deferred financing costs within other long-term assets and are amortized over the life of the facility. As of March 31, 2022 and December 31, 2021, KMF Land had unamortized debt issuance costs of $2.2 million and $2.1 million, respectively, in connection with its entry into the facility and subsequent amendments.

Deferred Rent

The Partnership recognizes rental expense for an operating lease on a straight-line basis over the term of the lease agreement. The deferred rent liability on the Partnership’s condensed consolidated balance sheets is attributable to the difference between rental expense (recognized on a straight-line basis) and the variable lease payments over the term of the agreement. The Partnership has historically leased office space under a single operating lease. In September 2021, the Partnership entered into an agreement to lease new office space under a different operating lease. In December 2021, the Partnership entered into a sublease of its current office space with an unaffiliated third-party.

Deposits for Property Acquisitions

Deposits are utilized for certain purchases of oil and gas properties. Such deposits are reclassified to oil and gas properties upon closure of the acquisitions. As of March 31, 2022, approximately $2.7 million related to acquisitions was classified as deposits for property acquisitions. As of December 31, 2021, there were no such balances.

Public Transaction Costs

General and administrative expense of $4.0 million for the three months ended March 31, 2022 included $1.2 million related to the merger with Falcon Minerals Operating Partnership, LP (“Falcon”). No such expense was recognized for the three months ended March 31, 2021.

 

3.

Revenue from Contracts with Customers

Oil and natural gas sales

Oil, natural gas and NGL sales revenues are generally recognized when control of the product is transferred to the customer, the performance obligations under the terms of the contracts with customers are satisfied and collectability is reasonably assured. All of the Partnership’s oil, natural gas and NGL sales are made under contracts with customers (operators). The performance obligations for the Partnership’s contracts with customers are satisfied at a point in time when control transfers at the wellhead, at which point payment is unconditional. Accordingly, the Partnership’s contracts do not give rise to contract assets or liabilities. The Partnership typically receives payment for oil, natural gas and NGL sales within 30 to 90 days of the month of delivery after initial production from the well. Such periods can extend longer due to factors outside of our control. The Partnership’s contracts for oil, natural gas and NGL sales are standard industry contracts that include variable consideration based on the monthly index price and adjustments that may include counterparty-specific provisions related to volumes, price differentials, discounts and other adjustments and deductions.

Lease bonus and other income

The Partnership also earns revenue from lease bonuses, delay rentals, and right-of-way payments. The Partnership generates lease bonus revenue by leasing its mineral interests to E&P companies. A mineral lease agreement represents our contract with a customer and generally transfers the rights, for a specified period of time, to explore for and develop any oil, natural gas and NGL discovered, grants us a specified royalty interest in the hydrocarbons produced from the leased property, and requires that drilling and completion operations commence within a specified time period. The Partnership recognizes lease bonus revenues when the lease agreement has been executed and payment is determined to be collectible. At the time the Partnership executes the lease agreement, the lease bonus payment is delivered to the Partnership. Upon receipt of the lease

 

F-10


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

bonus payment, the Partnership will release the recordable original lease documents to the customer. The Partnership also recognizes revenue from delay rentals to the extent drilling has not started within the specified period and payment has been received. Right-of-way payments are recorded by the Partnership when the agreement has been executed and payment is determined to be collectable. Payments for lease bonus and other income become unconditional upon the execution of an associated agreement. Accordingly, the Partnership’s lease bonus and other income transactions do not give rise to contract assets or liabilities.

Water sales

Historically, the Partnership earned revenue from water sales to various E&P operators located near its water supply assets. Water sales revenues are recognized when control of the water is transferred to the customer, the performance obligations under the terms of the contracts with customers are satisfied and collectability is reasonably assured. The performance obligations for the Partnership’s water sales are satisfied when control of the water is transferred to the customer, which may occur at the location of the Partnership’s water operations or at the customer’s well site. The Partnership’s water sales agreements are inherently short-term in nature and are executed on an as-needed basis with customers. The Partnership’s contracts for water sales are satisfied at the point in time when control of the water is transferred to the customer, at which point payment is unconditional. Accordingly, the Partnership’s contracts do not give rise to contract assets or liabilities.

In 2021, KMF Water was subject to an agreement (the “Water Services Agreement”) with a third-party water services company under which the third party agreed to manage the Partnership’s water assets and operations. In October of 2021, the agreement was terminated. See Note 12 for additional information.

Allocation of transaction price to remaining performance obligations

Oil and natural gas sales

The Partnership’s right to royalty income does not originate until production occurs and, therefore, is not considered to exist beyond each day’s production. Therefore, there are no remaining performance obligations under any of our royalty income contracts.

Lease bonus and other income

Given that the Partnership does not recognize lease bonus or other income until an agreement has been executed, at which point its performance obligation has been satisfied, the Partnership does not record revenue for unsatisfied or partially unsatisfied performance obligations as of the end of the reporting period.

Water leasing income

Given that the Partnership does not recognize water leasing income until the lessee receives payment from its customer, at which point Partnership’s performance obligation has been satisfied, the Partnership does not record revenue for unsatisfied or partially unsatisfied performance obligations as of the end of the reporting period.

Prior-period performance obligations

The Partnership records revenue in the month production is delivered to the purchaser. As a royalty interest owner, the Partnership has limited visibility into the timing of when new wells start producing as production statements may not be received for 30 to 90 days or more after the date production is delivered. As a result, the Partnership is required to estimate the amount of production delivered to the purchaser and the price that will be received for the sale of the product. The expected sales volumes and prices for these properties are estimated and recorded within accrued revenue and accounts receivable in the accompanying condensed consolidated balance sheets. The difference between the Partnership’s estimates of royalty income and the actual amounts received for oil and natural gas sales are recorded in the month that the royalty payment is received from the customer. For the three months ended March 31, 2022 and 2021, revenue recognized related to performance obligations satisfied in prior reporting periods was primarily attributable to production revisions by operators or amounts for which the information was not available at the time when revenue was estimated.

 

F-11


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

4.

Oil and Gas Properties

The Partnership has been and is engaged in the purchase of mineral rights in the Permian Basin in West Texas and southeastern New Mexico. The following is a summary of oil and natural gas properties as of March 31, 2022 and December 31, 2021 (in thousands):

 

Oil and natural gas properties:    March 31, 2022      December 31, 2021  

Unproved properties

   $ 795,736      $ 817,873  

Proved properties

     470,002        447,369  
  

 

 

    

 

 

 

Oil and natural gas properties, gross

     1,265,738        1,265,242  

Accumulated depletion and impairment

     (133,413      (118,175
  

 

 

    

 

 

 

Oil and natural gas properties, net

   $ 1,132,325      $ 1,147,067  
  

 

 

    

 

 

 

For the three months ended March 31, 2022, the Partnership paid $461 thousand related to capitalized transaction costs. For the three months ended March 31, 2021, the Partnership received proceeds of $105 thousand related to purchase price adjustments from prior acquisitions. For the three months ended March 31, 2021 the partnership paid $54 thousand related to purchase price adjustments from prior property sales.

 

5.

Acquisitions

Source Acquisition

In August 2021, KMF Land completed the acquisition of approximately 25,000 NRAs in the Midland and Delaware Basins from Source Energy Leasehold, LP and Permian Mineral Acquisitions, LP (together, “Source”). At close, subject to the terms and conditions of the transaction agreement, Source contributed its mineral and royalty interests to KMF Land and in consideration for the contribution, Kimmeridge affiliates caused DPM HoldCo to issue equity interests in DPM HoldCo to Source.

The Source acquisition was accounted for as an asset acquisition and, therefore, the acquired interests were recorded based on the fair value of the total assets acquired on the acquisition date. Based on the estimated fair values of the assets received, the Partnership recorded $183.2 million of the total consideration as unproved oil and gas property and $69.7 million as proved oil and gas property. Additionally, $3.5 million of transaction costs were capitalized related to the transaction.

Rock Ridge Acquisition

In June 2021, KMF Land completed the acquisition of approximately 18,700 NRAs from Rock Ridge Royalty, LLC (“RRR”). At close, subject to the terms and conditions of the transaction agreement, RRR contributed its mineral and royalty interests to KMF Land and in consideration for the contribution, Kimmeridge affiliates caused DPM HoldCo (a subsidiary of the Partnership and the sole member of KMF Land, LLC) to issue equity interests in DPM HoldCo to RRR.

The RRR acquisition was accounted for as an asset acquisition and, therefore, the acquired interests were recorded based on the fair value of the total assets acquired on the acquisition date. Based on the estimated fair values of the assets received, the Partnership recorded $190.3 million of the total consideration as unproved oil and gas property and $68.3 million as proved oil and gas property. Additionally, $1.1 million of transaction costs were capitalized related to the transaction.

Delaware ORRIs Acquisition

In October 2020, another partnership owned and managed by Kimmeridge, (“Fund V”), acquired a 2.0% (on an 8/8ths basis) overriding royalty interest in all of Callon Petroleum Company’s (“Callon”) operated assets in the Delaware, Midland and Eagle Ford Basins, proportionately reduced to Callon’s net revenue interest (the “Chambers ORRI”).

In June 2021, KMF Land entered into a definitive agreement to acquire 84% of the Delaware Basin portion of the Chambers ORRI from Chambers Minerals, LLC, a subsidiary of Fund V (the “Chambers Acquisition”). Immediately following the consummation of the contributions of assets to KMF Land, Chambers HoldCo, LLC (the managing member of Chambers Minerals, LLC) was issued equity in DPM HoldCo. As the general partner of Fund V and the General Partner of the Partnership are affiliated, the transaction was approved by the Partnership’s Limited Partner Advisory Committee on June 3, 2021.

 

F-12


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

The Chambers Acquisition was accounted for as an asset acquisition. The Chambers Acquisition was also accounted for as a transaction between entities under common control; the controlling ownership and management of the general partner of Fund V and the general partner of the Partnership have significant overlap, including responsibility for the management, control, and direction of the business affairs of the respective partnerships. As KMF Land and Fund V are entities under common control, the Partnership recorded the acquisition utilizing the properties’ net book value. The properties acquired by KMF Land had a historical net book value to Fund V at the time of sale of approximately $60.6 million ($45.3 million was allocated to unproved property and $15.3 million was allocated to proved property). Accordingly, the $37.5 million excess of the fair value of the properties above their net book value was recorded as a decrease to partners’ capital at the date of the transaction.

 

6.

Equity

Committed Capital

As of March 31, 2022 and December 31, 2021, the Partnership had aggregate capital commitments (the “Committed Capital”) of $618.4 million from Limited Partners and $8.0 million from the General Partner. At March 31, 2022 and December 31, 2021, approximately $29.5 million of this Committed Capital remained available to call for purposes of satisfying investment commitments, management fees, and expenses over the remaining life of the Partnership. As of March 31, 2022 and December 31, 2021, the Partnership’s contributed capital as a percentage of total Committed Capital was approximately 95%.

The General Partner may admit additional Subscription Limited Partners, or permit any existing Subscription Limited Partner to increase its Committed Capital, at one or more subsequent closings on or before the nine month anniversary of the Initial Closing except with respect to the Extended Closing Date and the Second Extended Closing Date. The General Partner and each Subscription Limited Partner that is admitted or that increases its Committed Capital at a Subsequent Closing shall make, at such Subsequent Closing, Capital Contributions for Investments, Management Fees, and Expenses such that such partners’ Capital Contributions included or made as of the date of the Subsequent Closing are equal to their Pro Rata Share of such amounts made by the Partnership as of the date of such Subsequent Closing.

Allocation of Partners’ Net Profits and Losses

In accordance with the Partnership Agreement, net profit or net loss is generally allocated among the Capital Accounts of the Partners in accordance with the following distribution methodology.

Partners’ Distributions

Subject to the provisions of the Partnership Agreement, investment proceeds shall be distributed to the Partners, in proportion to each of their respective percentage interests, as follows:

(i) First—100% to such Limited Partner until such Limited Partner has received cumulative distributions pursuant to this clause (i) in an amount equal to all Capital Contributions of such Limited Partner (whether such Capital Contributions were made to fund Investments, utilized for the payment of Partnership Expenses, Management Fees or applied for any other purpose);

(ii) Second—100% to such Limited Partner until the cumulative distributions to such Limited Partner represents an 8% per annum (compounded annually) internal rate of return on the Capital Contributions of such Limited Partner referred to in clause (i) above calculated from the due date specified in the applicable Payment Notice until the date of the distribution (the “Preferred Return Amount”);

(iii) Third—50% to the General Partner and 50% to such Limited Partner until the General Partner has received distributions pursuant to this clause (iii) equal to the sum of (A) the ratio of such Limited Partner’s Capital Contribution to the total Capital Contributions of all Limited Partners multiplied by the General Partner’s aggregate Capital Contribution plus (B) 20% of the sum of (Y) the amount distributed to such Limited Partner pursuant to clause (ii) above and (Z) the amount distributed to such Limited Partner and to the General Partner with respect to such Limited Partner pursuant to this clause (iii); and

 

F-13


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

(iv) Thereafter—80% to such Limited Partner and, 20% to the General Partner.

Upon the final distribution of proceeds attributable to the Partnership’s investments, the General Partner, if required, must return to the Limited Partners, in proportion to their capital contributions used to fund the Partnership’s investments an aggregate amount, not to exceed the General Partner’s reallocation, to assure that the total distributions of proceeds attributable to the Partnership’s investments are made in accordance with the above formula.

 

7.

Derivative Instruments

Commodity Derivatives

KMF Land may enter into commodity derivative contracts to manage its exposure to oil and gas price volatility associated with its production. These derivatives are not entered into for trading or speculative purposes. While the use of these instruments limits the downside risk of adverse commodity price changes, their use may also limit future cash flows from favorable commodity price changes. Depending on changes in oil and gas futures markets and management’s view of underlying supply and demand trends, the Partnership may increase or decrease its derivative positions. The Partnership’s commodity derivative contracts have not been designated as hedges for accounting purposes; therefore, all gains and losses on commodity derivatives are recognized in the Partnership’s statement of income.

The Partnership may utilize fixed price swaps and basis swaps to manage commodity price risks. The Partnership has entered into these contracts when management believes that favorable future sales prices for the Partnership’s production can be secured. Under fixed price swap agreements, when actual commodity prices upon settlement exceed the fixed price provided by the swap contracts, the Partnership pays the difference to the counterparty. When actual commodity prices upon settlement are less than the contractually provided fixed price, the Partnership receives the difference from the counterparty. The partnership may also enter into basis swap contracts in order to hedge the difference between the New York Mercantile Exchange (“NYMEX”) index price and a local index price that is representative of the price received by many of the operators in the Permian Basin.

KMF Land’s oil and gas swap contracts as of March 31, 2022 are summarized below:

 

     Oil (NYMEX WTI)  
Remaining Term    Bbl per Day      Weighted Average Price per Bbl  

April 2022 - December 2022

     200      $ 91.70  

January 2023 - December 2023

     200      $ 78.30  

January 2024 - December 2024

     200      $ 72.05  

 

     Gas (NYMEX Henry Hub)  
Remaining Term    MMBtu per Day      Weighted Average Price per MMBtu  

April 2022 - December 2022

     500      $ 4.63  

January 2023 - December 2023

     500      $ 3.83  

January 2024 - December 2024

     500      $ 3.41  

KMF Land was not party to any derivative contracts as of December 31, 2021.

 

F-14


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

Financial Summary

The following table presents a summary of KMF Land’s derivative instruments and where such values are recorded on the condensed consolidated balance sheet as of March 31, 2022:

 

     March 31, 2022  
     Balance sheet
location
     Fair value
(In thousands)
 

Asset derivatives not designated as hedges for accounting purposes:

     

Commodity contracts

     Current assets      $ —    

Commodity contracts

     Long-term assets        —    
     

 

 

 

Total asset derivatives

        —    
     

 

 

 

Liability derivatives not designated as hedges for accounting purposes:

 

  

Commodity contracts

     Current liabilities        (468

Commodity contracts

    
Long-
term liabilities

 
     (646
     

 

 

 

Total liability derivatives

        (1,114
     

 

 

 

Net derivatives

      $ (1,114
     

 

 

 

The following table presents the gross fair values of recognized derivative assets and liabilities, the amounts offset under master netting arrangements with counterparties, and the resulting net amounts presented on the condensed consolidated balances sheet (in thousands):

 

     March 31, 2022  
     Gross
amounts on
balance sheet
     Gross amounts
offset on balance
sheet
     Net amounts of assets
on balance sheet
 

Commodity derivative assets

   $ —          —          —    

Commodity derivative liabilities

   $ (1,114      —          (1,114

The following table is a summary of derivative gains and losses, and where such values are recorded in the condensed consolidated statements of income for the three months ended March 31, 2022 and 2021 (in thousands):

 

     Statement of
income location
     Three months ended
March 31, 2022
     Three months ended
March 31,
2021
 

Commodity derivative losses

     Other expense      $ (1,114    $          —    

The fair value of commodity derivative instruments was determined using Level 2 inputs.

 

8.

Long-Term Debt

Revolving Credit Facility

KMF Land is party to a credit agreement with a syndicate of banks led by Bank of America N.A. as Administrative Agent, Issuing Bank and Syndication Agent, and Capital One National Association and Barclays Bank PLC as Co-Documentation Agents (the “Revolving Credit Facility”).

Availability under our Revolving Credit Facility is governed by a borrowing base, which is subject to redetermination semi-annually each year. In addition, lenders holding two-thirds of the aggregate commitments may request one additional redetermination each year. The Partnership can also request one additional redetermination each year, and such other redeterminations as appropriate when significant acquisition opportunities arise. The borrowing base is subject to further adjustments for asset dispositions, material title deficiencies, certain terminations of hedge agreements and issuances of permitted additional indebtedness. Increases to the borrowing base requires unanimous approval of the lenders, while decreases only require approval of lenders holding two-thirds of the aggregate commitments at such time. The determination

 

F-15


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

of the borrowing base takes into consideration the estimated value of KMF Land’s oil and gas mineral interests in accordance with the lenders’ customary practices for oil and gas loans. The Revolving Credit Facility is guaranteed by KMF Land and is collateralized by substantially all of the assets of KMF Land.

In June 2021, KMF Land and the Partnership entered into the Fourth Amendment to Credit Agreement (the “Fourth Amendment”). The Fourth Amendment, among other things, allowed for the consummation of the acquisitions described in Note 5.

In October 2021, KMF Land and DPM HoldCo entered into the Amended and Restated Credit Agreement with a syndicate of banks led by Bank of America N.A. as Administrative Agent, Issuing Bank and Syndication Agent. Pursuant to the Amended and Restated Credit Agreement, the initial borrowing base under the new facility is $150.0 million.

As of March 31, 2022, the borrowing base was $150.0 million as determined by the lenders and the outstanding balance under our Revolving Credit Facility was $94.0 million. As of December 31, 2021, the borrowing base was $150.0 million as determined by the lenders and the outstanding balance under our Revolving Credit Facility was $134.0 million.

The Revolving Credit Facility bears interest at a rate per annum equal to, at our option, the adjusted base rate or the adjusted LIBOR rate plus an applicable margin. The applicable margin is based on utilization of our Revolving Credit Facility and ranges from (a) in the case of adjusted base rate loans, 1.500% to 2.500% and (b) in the case of adjusted LIBOR rate loans, 2.500% to 3.500%. The Partnership may elect an interest period of one, two, three, six, or if available to all lenders, twelve months. Interest is payable in arrears at the end of each interest period, but no less frequently than quarterly. A commitment fee is payable quarterly in arrears on the daily undrawn available commitments under our Revolving Credit Facility in an amount ranging from 0.375% to 0.500% based on utilization of our Revolving Credit Facility. The Revolving Credit Facility is subject to other customary fee, interest and expense reimbursement provisions.

As of March 31, 2022 and December 31, 2021, the weighted average interest rate related to our outstanding borrowings was 3.33% and 3.36%, respectively. As of March 31, 2022 and December 31, 2021, KMF Land had unamortized debt issuance costs of $2.2 million and $2.1 million, respectively, in connection with its entry into the facility and subsequent amendments. Such costs are capitalized as deferred financing costs within other long-term assets and are amortized over the life of the facility. For the three months ended March 31, 2022 and 2021, we recognized $204 thousand and $67 thousand, respectively, in interest expense related to the amortization of deferred financing costs.

Our Revolving Credit Facility matures on September 26, 2024. Loans drawn under our Revolving Credit Facility may be prepaid at any time without premium or penalty (other than customary LIBOR breakage) and must be prepaid in the event

that exposure exceeds the lesser of the borrowing base and the elected availability at such time. The principal amount of loans that are prepaid are required to be accompanied by accrued and unpaid interest and fees on such amounts. Loans that are prepaid may be reborrowed. In addition, the Partnership may permanently reduce or terminate in full the commitments under our Revolving Credit Facility prior to maturity. Any excess exposure resulting from such permanent reduction or termination must be prepaid. Upon the occurrence of an event of default under our Revolving Credit Facility, the administrative agent acting at the direction of the lenders holding a majority of the aggregate commitments at such time may accelerate outstanding loans and terminate all commitments under our Revolving Credit Facility, provided that such acceleration and termination occurs automatically upon the occurrence of a bankruptcy or insolvency event of default.

Our Revolving Credit Facility contains customary affirmative and negative covenants, including, without limitation, reporting obligations, restrictions on asset sales, restrictions on additional debt and lien incurrence and restrictions on making distributions (subject only to no default or borrowing base deficiency) and investments. In addition, our Revolving Credit Facility requires us to maintain (a) a current ratio of not less than 1.00 to 1.00 and (b) a ratio of total net funded debt to consolidated EBITDA of not more than 3.50 to 1.00. EBITDA for the period ending on March 31, 2022 is equal to EBITDA for the period beginning on July 1, 2021 and ending on March 31, 2022, multiplied by four-thirds. The Partnership was in compliance with the terms and covenants of the Revolving Credit Facility at March 31, 2022 and December 31, 2021.

 

F-16


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

9.

Fair Value Measurement

The Partnership is subject to ASC 820, Fair Value Measurements and Disclosures. ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). Inputs are used in applying the various valuation techniques and broadly refer to the assumptions that market participants use to make valuation decisions, including assumptions about risk. Inputs may include price information, volatility statistics, specific and broad credit data, liquidity statistics, and other factors. A financial instrument’s level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. However, the determination of what constitutes “observable” requires significant judgment by Management. Management considers observable data to be market data which is readily available, regularly distributed or updated, reliable and verifiable, not proprietary, and provided by independent sources that are actively involved in the relevant market. The categorization of a financial instrument within the hierarchy is based upon the pricing transparency of the instrument and does not necessarily correspond to Management’s perceived risk of that instrument.

Level 1—Fair values are based on unadjusted quoted prices in active markets that are accessible at the measurement date of identical, unrestricted assets.

Level 2—Fair values are based on quoted prices for markets that are not active or financial instruments for which all significant inputs are observable, either directly or indirectly.

Level 3—Inputs that are unobservable and significant to the overall fair value measurement and include situations where there is little, if any, market activity for the asset or liability.

The Partnership’s proved oil and gas properties are assessed for impairment on a periodic basis. If the Partnership’s proved properties are determined to be impaired, the carrying basis of the properties is adjusted down to fair value. This represents a fair value measurement that would qualify as a non-recurring Level 3 fair value measurement. The fair value represents Management’s best estimate using the inputs available as of March 31, 2022 and 2021. No impairment of proved properties was recorded for the three months ended March 31, 2022 and 2021.

The fair value of the Partnership’s derivative instruments (Level 2) was estimated using discounted cash flows and credit risk adjustments. See Note 7 for further information on the fair value of our derivative instruments.

 

10.

Related Party Transactions

Management Fees

The Partnership has entered into a management services arrangement with Kimmeridge Energy Management Company, LLC (the “Manager”).

As compensation for services rendered in the management of the Partnership, the Partnership will pay the Manager with respect to each Limited Partner an annual management fee (“Management Fee”) computed on a daily basis from the date of the Initial Closing. Limited Partners who increased their Commitment to the Partnership at the Extended Closing Date will only be required to pay Management Fees with respect to their increased Commitment from and after the Extended Closing Date. Limited Partners who increased their Commitments on the Second Extended Closing Date will not be obligated to pay Management Fees with respect to such increased Commitments until after the Commitment Period Expiration Date. The Management Fee will be paid in quarterly installments on the first business day of each Fiscal Quarter with each installment to be equal to one-quarter of the amount that would be payable on the last day of its preceding Fiscal Quarter. Until the earlier of (A) the Commitment Period Expiration Date and (B) the date that the General Partner, any Principal or any Affiliate thereof first accrues or is paid a Management Fee, advisory fee or similar fee with respect to a Successor Fund (the earlier of the dates referred to in (A) or (B) being the “Initial Step-Down Date”), 2% per annum of such Limited Partner’s Commitment.

 

 

F-17


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

Beginning on the day after the Initial Step-Down Date and until the earlier of (A) termination of the Partnership pursuant to Article IX of the Partnership Agreement and (B) the sixth anniversary of the Final Closing (the earlier of the dates referred to in (A) or (B) being the “Second Step-Down Date”), 2% per annum of such Limited Partner’s pro rata share of the cost basis of all Investments held by the Partnership as of the end of the immediately preceding Fiscal Quarter less the value of Investments which have been written-off as a result of a permanent impairment.

Beginning on the day after the Second Step-Down Date and until the termination of the Partnership, 1% per annum of such Limited Partner’s pro rata share of the cost basis of all Investments held by the Partnership as of the end of the immediately preceding Fiscal Quarter less the value of Investments which have been written-off as a result of a permanent impairment.

Each quarterly installment of the Management Fee calculated with respect to each Limited Partner, shall be reduced by the Limited Partner’s pro rata percentage (based on Capital Contributions) of any application fees, closing fees, breakup fees or similar fees associated with an Investment or proposed investment and other routine fees, received by the General Partner during the quarter. If the credited amounts exceed the quarterly Management Fee payment next due and payable, such excess shall be carried forward from quarter to quarter to reduce the Management Fee payable in future periods. For the three months ended March 31, 2022 and 2021 there were no adjustments or credited amounts and the Manager earned and was paid approximately $1.9 million and $1.9 million in Management Fees relating to management services, respectively.

Common Control Transaction

The Partnership has acquired oil and gas properties from separate limited partnerships whereby the General Partner of the Partnership and the general partner of the separate limited partnerships are affiliated. These transactions were accounted for as a reduction to partners’ capital as the affiliated entities were under common control. The following transaction was completed during the year ended December 31, 2021:

Delaware ORRIs Acquisition

In October 2020, another partnership owned and managed by Kimmeridge acquired a 2.0% (on an 8/8ths basis) overriding royalty interest in all of Callon’s operated assets in the Delaware, Midland and Eagle Ford Basins, proportionately reduced to Callon’s net revenue interest.

In June 2021, KMF Land entered into a definitive agreement to acquire 84% of the Delaware Basin portion of the Chambers ORRI from Chambers Minerals, LLC, a subsidiary of Fund V. Immediately following the consummation of the contributions of assets to KMF Land, Chambers HoldCo, LLC (the managing member of Chambers Minerals, LLC) was issued equity in DPM HoldCo. As the general partner of Fund V and the General Partner of the Partnership are affiliated, the transaction was approved by the Partnership’s Limited Partner Advisory Committee on June 3, 2021.

The Chambers Acquisition was accounted for as an asset acquisition. The Chambers Acquisition was also accounted for as a transaction between entities under common control; the controlling ownership and management of the general partner of Fund V and the general partner of the Partnership have significant overlap, including responsibility for the management, control, and direction of the business affairs of the respective partnerships. As KMF Land and Fund V are entities under common control, the Partnership recorded the acquisition utilizing the properties’ net book value. The properties acquired by KMF Land had a historical net book value to Fund V at the time of sale of approximately $60.6 million ($45.3 million was allocated to unproved property and $15.3 million was allocated to proved property). Accordingly, the $37.5 million excess of the fair value of the properties above their net book value was recorded as a decrease to partners’ capital at the date of the transaction.

Cost Reimbursements and Allocations from Affiliates

General and administrative expenses and certain capitalizable costs are not directly associated with the generation of the Partnership’s revenues and include costs such as employee compensation, office expenses and fees for professional services. These costs are allocated on a “time spent” basis, a pro rata basis, or by another manner which is designed to be fair and equitable. Some of those costs are incurred on the Partnership’s behalf and allocated to the Partnership by the Manager and its affiliates and reimbursed by the Partnership. These costs may not be indicative of costs incurred by the

 

F-18


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

Partnership had such services been provided by an unaffiliated company during the period presented. We have not estimated what these costs and expenses would be if they were incurred by the Partnership on a standalone basis as such estimate would be impractical and lack precision. We believe the methodology utilized by Kimmeridge Operations and the Manager for the allocation of these costs to be reasonable.

Kimmeridge Operations Reimbursements

From time to time, the Partnership reimburses Kimmeridge Operations, LLC (“Kimmeridge Operations”), a wholly owned subsidiary of the Manager and affiliate of the Partnership, for general and administrative expenses. As a subsidiary of the Manager, Kimmeridge Operations staff perform land and administrative services on behalf of the Partnership. For the three months ended March 31, 2022 and 2021, the Partnership reimbursed Kimmeridge Operations for approximately $6 thousand and $1.1 million related to these services. As of March 31, 2022 and December 31, 2021, there were no amounts due to Kimmeridge Operations.

Kimmeridge Energy Management Company Reimbursements

From time to time, the Partnership reimburses the Manager for investments and expenses prefunded on behalf of the Partnership. For the three months ended March 31, 2022 and 2021, the Partnership reimbursed the Manager for approximately $142 thousand and $55 thousand, respectively. As of March 31, 2022 and December 31, 2021, approximately $121 thousand and $142 thousand was due to the Manager, respectively.

 

11.

Commitment and Contingencies

The Partnership leases office space under an operating lease. In September 2021, the Partnership entered into an agreement to lease new office space under a different operating lease. In December 2021, the Partnership entered into a sublease of its current office space with an unaffiliated third-party. Future minimum lease commitments under the lease as of March 31, 2022 are presented below (in thousands):

 

Year    Total  

2022

   $ 441  

2023

     600  

2024

     614  

2025

     628  

2026

     643  

2027

     658  

Thereafter

     875  
  

 

 

 

Total

   $ 4,459  
  

 

 

 

Legal Proceedings

From time to time, the Partnership may be involved in various legal proceedings, lawsuits, and other claims in the ordinary course of business including proceedings related to environmental and other matters. Such matters are subject to many uncertainties, and outcomes are not predictable with assurance. Management does not believe that the resolution of these matters will have a material adverse impact on our financial condition, cash flows or results of operations.

 

12.

Lease Income

In April 2020, KMF Water entered into the Water Services Agreement with a third-party water services company under which the third party agreed to manage the Partnership’s water assets and operations for an initial term of three months. Under the terms of the agreement, the third party is responsible for the production, marketing, and sales of water from the Partnership’s water properties, but each entity will each be entitled to fifty percent of the proceeds generated from water sales. The agreement also prescribes which entity (KMF or the third party) will be responsible for various costs under the arrangement. The initial term has been renewed for successive three-month periods and will continue to automatically renew for successive three-month terms unless terminated. The agreement was terminated in October 2021.

 

F-19


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

The Water Services Agreement constituted a leasing arrangement under which the Partnership was a lessor. Under the terms of the agreement, the Partnership was not entitled to any income until the lessee has completed a water sale and received payment from its customer. The Partnership did not accrue this contingent rental income until the lessee has received payment. Leasing income related to the Water Sales Agreement was $0.2 million during the three months ended March 31, 2021. No such income was recognized for the three months ended March 31, 2022.

 

13.

Business Segment Information

The Partnership has two reportable segments: Oil and Gas Producing Activities and Water Service Operations. The segments provide the chief operating decision maker (“CODM”) with a comprehensive financial view of the Partnership’s core business. The Partnership’s Management has been determined to be the CODM. The CODM assesses performance and allocates resources based on the two reportable segments.

The Oil and Gas Producing Activities segment is comprised of managing the mineral and royalty interests and related revenue streams of KMF Land. The revenue streams of this segment principally consist of royalties from oil, natural gas and NGL producing activities and revenues from lease bonus payments and easements. We are not a producer and the Partnership’s oil, natural gas, and NGL revenues are derived from a fixed percentage of the oil, natural gas and NGL produced from the acreage underlying our interests, net of post-production expenses and production taxes. The Water Service Operations segment comprises the water supply assets and operations of KMF Water.

The Partnership evaluates the performance of its operating segments based on operating revenues and segment profit. Operating segments are defined as components of an enterprise for which separate financial information is evaluated regularly by the CODM in deciding how to allocate resources and assess performance. Segment profit is defined as segment revenues less operating expenses, depreciation, depletion and amortization, income taxes, and interest expense. Partnership expenses include general expenses associated with managing the Partnership and are not allocated directly to the two reportable segments.

The following table sets forth certain financial information with respect to the Partnership’s reportable segments (in thousands):

 

     For the three months ended March 31, 2022  
     Oil and Gas
Producing
Activities
     Water
Service
Operations
     Partnership      Consolidated
Total
 

Revenues

   $ 66,261      $ 102      $ —        $ 66,363  

Depreciation, depletion and amortization

     15,313        72        —          15,385  

Income tax expense

     (491      —          (25      (516

Interest expense

     (1,176      —          —          (1,176

Segment profit (loss)

     40,446        21        (1,953      38,514  

Total assets as of March 31, 2022

     1,199,215        3,250        2,120        1,204,585  

Capital expenditures including mineral acquisitions

     676        —          —          676  

A reconciliation of segment profit (loss) to net income is as follows:

 

Segment profit

   $ 38,514  

Interest income

     8  

Net income attributable to noncontrolling interests

     19,242  

Net income attributable to partners

     19,280  

 

 

F-20


KIMMERIDGE MINERAL FUND, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

FOR THE THREE MONTHS ENDED MARCH 31, 2022 AND 2021

(UNAUDITED)

 

 

     For the three months ended March 31, 2021  
     Oil and Gas
Producing
Activities
     Water
Service
Operations
     Partnership      Consolidated
Total
 

Revenues

   $ 16,847      $ 202      $ —        $ 17,049  

Depreciation, depletion and amortization

     6,793        72        —          6,865  

Income tax expense

     (81      —          —          (81

Interest expense

     (307      —          —          (307

Segment profit (loss)

     6,259        130        (1,914      4,475  

Total assets as of March 31, 2021

     588,979        3,529        2,143        594,651  

Capital expenditures (reimbursements) including mineral acquisitions

     (105      —          —          (105

A reconciliation of segment profit (loss) to net income is as follows:

 

Segment profit

   $ 4,475  

Interest income

     1  

Net income

     4,476  

 

14.

Merger with Falcon Minerals

On January 11, 2022, DPM HoldCo, LLC entered into an Agreement and Plan of Merger with Falcon, pursuant to which Falcon will merge with and into DPM HoldCo, LLC, with DPM HoldCo, LLC continuing as the surviving entity in the Merger in an all-stock transaction, subject to Falcon shareholder approval.

 

15.

Subsequent Events

Management has evaluated all events subsequent to the balance sheet date for disclosure within these financial statements.

 

 

F-21

Exhibit 99.5

MANAGEMENT’S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS OF DESERT PEAK

The following discussion and analysis should be read in conjunction with the audited consolidated financial statements and notes thereto for the years ended December 31, 2021, 2020 and 2019 of Kimmeridge Mineral Fund, L.P. (“Desert Peak,” “KMF,” “our,” or “we”) appearing as Exhibit 99.3 to this Current Report on Form 8-K (the “Form 8-K”), the interim unaudited condensed consolidated financial statements and notes thereto for the three months ended March 31, 2022 and 2021 appearing as Exhibit 99.4 to the Form 8-K, and the definitive proxy statement filed with the Securities and Exchange Commission (“SEC”) on May 5, 2022 (the “Proxy Statement”). The discussion and analysis should also be read together with the unaudited pro forma condensed consolidated combined financial information appearing as Exhibit 99.6 to this Form 8-K. Unless otherwise indicated, the historical financial information in this “Management’s Discussion and Analysis of Financial Condition and Results of Operations” reflects only the historical financial results of Desert Peak prior to the consummation of the transactions contemplated by the Agreement and Plan of Merger (the “Merger Agreement”) between Sitio Royalties Corp. (formerly known as Falcon Minerals Corporation), Sitio Royalties Operating Partnership, LP, a Delaware limited partnership (formerly known as Falcon Minerals Operating Partnership, LP, “Sitio OpCo”), Ferrari Merger Sub A LLC, a Delaware limited liability company (“Merger Sub”), and DPM HoldCo, LLC, a Delaware limited liability company (“Desert Peak”), pursuant to which Merger Sub merged with and into Desert Peak (the “Merger”), with Desert Peak continuing as the surviving entity in the Merger as a wholly owned subsidiary of Sitio OpCo. The transactions contemplated by the Merger Agreement are referred to herein as the “Merger Transactions.”

The following discussion contains “forward-looking statements” that reflect our future plans, estimates, beliefs, and expected performance. The forward-looking statements are dependent upon events, risks and uncertainties that may be outside our control. Actual results and the timing of events may differ materially from those contained in these forward-looking statements due to several factors which include, but are not limited to market prices for oil, natural gas and natural gas liquids (“NGLs”), production volumes, estimates of proved reserves, capital for mineral acquisitions, economic and competitive conditions, regulatory changes and other uncertainties, as well as those factors discussed below and elsewhere in this Form 8-K and those discussed in the sections entitled “Risk Factors” and “Cautionary Note Regarding Forward-Looking Statements” in the Proxy Statement. We do not undertake any obligation to publicly update any forward-looking statements except as otherwise required by applicable law.

Overview

As of March 31, 2022, we owned mineral and royalty interests representing 105,427 NRAs when adjusted to a 1/8th royalty. For the three months ended March 31, 2022, the average net daily production associated with our mineral and royalty interests was 11,387 BOE/d, consisting of 5,948 Bbls/d of oil, 18,826 Mcf/d of natural gas and 2,301 Bbls/d of NGLs. Since our formation in November 2016, we have accumulated our acreage position by making 180 acquisitions. We expect to continue to grow our acreage position by making acquisitions that meet our investment criteria for geologic quality, operator capability, remaining growth potential, cash flow generation and, most importantly, rate of return.

Our mineral and royalty interests entitle us to receive a fixed percentage of the revenue from crude oil, natural gas and NGLs produced from the acreage underlying our interests. Unlike owners of working interests in oil and gas properties, we are not obligated to fund drilling and completion costs, plugging and abandonment costs or lease operating expenses associated with oil and gas production. As a mineral and royalty owner, we incur only our proportionate share of production and ad valorem taxes and, in some cases, gathering, processing and transportation costs which reduce the amount of revenue we recognize. For the three months ended March 31, 2022, our production and ad valorem taxes were approximately $3.63 per BOE, relative to an average realized price of $63.38 per BOE. As a result, our operating margin and cash flows are higher, as a percentage of revenue, than those of traditional E&P companies. We do not anticipate engaging in any activities, other than acquisitions, that will incur capital costs. We believe our cost structure and business model will allow us to return a significant amount of our cash flows to stockholders.

We have historically had two reportable segments: Oil and Gas Producing Activities and Water Service Operations.


The Oil and Gas Producing Activities segment is comprised of managing our mineral and royalty interests and related revenue streams, which principally consist of royalties from crude oil, natural gas and NGLs producing activities and revenues from lease bonuses, delay rentals and easements. We are not a producer, and our crude oil, natural gas and NGLs revenue is derived from a fixed percentage of the crude oil, natural gas and NGLs produced by E&P operators from the acreage underlying our interests, net of post-production expenses and taxes.

The Water Service Operations segment is comprised of our water supply assets and revenues. The income of this segment consists of the sale of water to various Permian Basin E&P operators produced from our water supply assets. In connection with the Merger Transactions, Desert Peak will not contribute the Water Service Operations business or assets, and we anticipate that the Post-Combination Company will have one reportable segment after completion of the Merger Transactions.

Recent Developments

Credit Facility

On October 8, 2021, KMF Land, LLC, a Delaware limited liability company (“KMF Land”), as borrower, Desert Peak, as parent, Bank of America, N.A., as the administrative agent and issuing bank, and certain lenders entered into that certain Amended and Restated Credit Agreement (as amended, restated, supplemented or otherwise modified and as in effect immediately prior to the Closing Date, the “Existing Credit Agreement”), pursuant to which the lenders thereunder made loans and other extensions of credit to the borrower thereunder.

On June 7, 2022 (the “Closing Date”), the Existing Credit Agreement was amended and restated in its entirety pursuant to a Second Amended and Restated Credit Agreement (as amended, restated, supplemented or otherwise modified from time to time, the “Credit Agreement”) entered into by Sitio OpCo, as borrower, KMF Land, Bank of America, N.A., as the administrative agent and issuing bank, the lenders party thereto (the “Lenders”) and other financial institutions from time to time party thereto. The Credit Agreement has a scheduled maturity date in June 2026 and provides for an aggregate principal amount of up to $750 million. As of the Closing Date, the Credit Agreement had a $300 million borrowing base and $300 million elected commitment amount. As part of the aggregate commitments under the revolving advances, the Credit Agreement provides for letters of credit to be issued at the request of the borrower in an aggregate amount not to exceed $15 million. Existing letters of credit in place under our revolving credit facility immediately prior to the Closing Date are continued and now deemed issued under and governed by the terms of the Credit Agreement. Please see the “—Our Revolving Credit Facility” for a description of the material terms of the Credit Agreement.

Acquisitions

As of March 31, 2022, we have evaluated over 1,000 potential mineral and royalty interest acquisitions and completed 180 acquisitions from landowners and other mineral interest owners. We intend to capitalize on our management team’s expertise and relationships to continue to make value-enhancing mineral and royalty interest acquisitions in the Permian Basin designed to increase our cash flows per share. In connection with the market conditions resulting from the COVID-19 pandemic, our acquisition activity saw a significant decline during 2020 but rebounded in 2021.

Production and Operations

Our average daily production during the three months ended March 31, 2022 and 2021 was 11,387 BOE/d (52% crude oil) and 4,885 BOE/d (43% crude oil), respectively. For the three months ended March 31, 2022, we received an average of $92.04 per Bbl of crude oil, $4.63 per Mcf of natural gas and $37.81 per Bbl of NGLs, for an average realized price of $63.38 per BOE. For the three months ended March 31, 2021, we received an average of $54.81 per Bbl of crude oil, $3.66 per Mcf of natural gas and $29.29 per Bbl of NGLs, for an average realized price of $37.42 per BOE.

Our average daily production during the years ended December 31, 2021, 2020 and 2019 was 6,989 BOE/d (49% crude oil), 5,764 BOE/d (44% crude oil) and 4,793 BOE/d (47% crude oil), respectively. For the year ended December 31, 2021, we received an average of $67.29 per Bbl of crude oil, $3.61 per Mcf of natural gas and $33.22 per Bbl of NGLs, for an average realized price of $46.47 per BOE. For the year ended December 31, 2020, we


received an average of $37.40 per Bbl of crude oil, $1.03 per Mcf of natural gas and $10.32 per Bbl of NGLs, for an average realized price before derivatives of $20.95 per BOE. For the year ended December 31, 2019, we received an average of $52.90 per Bbl of crude oil, $0.74 per Mcf of natural gas and $13.48 per Bbl of NGLs, for an average realized price of $29.09 per BOE.

As of March 31, 2022, we had 4,646 gross (37.974 net) producing horizontal wells on our acreage. Additionally, as of March 31, 2022, there were 712 gross (4.982 net) horizontal wells in various stages of drilling or completion and 439 gross active horizontal drilling permits on our acreage.

As of December 31, 2021, we had 4,459 gross (36.887 net) producing horizontal wells on our acreage. Additionally, as of December 31, 2021, there were 659 gross (4.644 net) horizontal wells in various stages of drilling or completion and 533 active horizontal drilling permits on our acreage. As of December 31, 2020, we had 1,650 gross (17.767 net) producing horizontal wells on our acreage. Additionally, as of December 31, 2020, there were 196 gross (2.123 net) horizontal wells in various stages of drilling or completion and 207 active horizontal drilling permits on our acreage. As of December 31, 2019, we had 1,270 gross (14.715 net) producing horizontal wells on our acreage. Additionally, as of December 31, 2019, there were 321 gross (2.461 net) horizontal wells in various stages of drilling or completion and 133 active horizontal drilling permits on our acreage.

COVID-19 Pandemic

The initial outbreak of COVID-19 caused a disruption to the oil and natural gas industry and to our business by, among other things, contributing to a significant decrease in global crude oil demand and the price for oil in 2020. This disruption was somewhat alleviated in 2021 and 2022, with the increase in domestic vaccination programs and reduced spread of the COVID-19 virus contributing to an improvement in the economy and higher realized prices for commodities. Since mid-2020 through mid-2022, oil prices have generally improved, with demand steadily increasing despite the uncertainties surrounding the COVID-19 variants, which have continued to inhibit a full global demand recovery. However, the current price environment remains uncertain as responses to the COVID-19 pandemic and newly emerging variants of the virus continue to evolve. Furthermore, although certain E&P operators of our mineral and royalty interests announced reductions to their capital budgets for 2021 and beyond in connection with the outbreak of COVID-19, many operators have resumed or increased drilling and completion activities compared to activity levels in 2020 in connection with the increase in commodity prices since mid-2020. Given the dynamic nature of these events, Desert Peak cannot reasonably estimate the period of time that the COVID-19 pandemic and related market conditions will persist and the impacts on our business from the COVID-19 pandemic, efforts to fight the pandemic and other market events.

The impact of recent developments in Ukraine

In February 2022, Russia launched a large-scale invasion of Ukraine that has led to significant armed hostilities. As a result, the United States, the United Kingdom, the member states of the European Union and other public and private actors have levied severe sanctions on Russian financial institutions, businesses and individuals. This conflict, and the resulting sanctions, has contributed to significant increases and volatility in the price for oil and natural gas, with the posted price for WTI reaching a high of $123.64 per barrel. This volatility could negatively impact commodity prices and cause rising inflation that could impact demand for refined products. Given the uncertain timing of a return of refined product demand to historical levels, the extent these events will have an impact on our results of operations is unclear. The geopolitical and macroeconomic consequences of this invasion and associated sanctions cannot be predicted, and such events, or any further hostilities in Ukraine or elsewhere, could severely impact the world economy and may adversely affect our financial condition. The Russian conflict with Ukraine continues to evolve, and the extent to which these events may impact our business, financial condition, liquidity, results of operations, and prospects will depend highly on future developments, which are very uncertain and cannot be predicted with confidence.

How We Evaluate Our Operations

We use a variety of operational and financial measures to assess our performance. Among the measures considered by management are the following:

 

   

volumes of oil, natural gas and NGLs produced;


   

number of rigs on our acreage and number of producing wells, spud wells and permitted wells;

 

   

commodity prices; and

 

   

Adjusted EBITDA.

Volumes of Oil, Natural Gas and NGLs Produced

In order to track and assess the performance of our assets, we monitor and analyze our production volumes from our mineral and royalty interests. We also regularly compare projected volumes to actual reported volumes and investigate unexpected variances.

Number of Rigs on our Acreage, Spud Wells and Permitted Wells

In order to track and assess the performance of our assets, we monitor and analyze the number of rigs currently drilling on our properties. We also constantly monitor the number of permitted wells, spud wells, completions, and producing wells on our mineral and royal interests in an effort to evaluate near-term production growth.

Commodity Prices

Historically, oil, natural gas and NGL prices have been volatile and may continue to be volatile in the future. During the past five years, the posted price for WTI has ranged from a low of negative ($36.98) per barrel in April 2020 to a high of $123.64 per barrel in March 2022. The Henry Hub spot market price for natural gas has ranged from a low of $1.33 per MMBtu in September 2020 to a high of $23.86 per MMBtu in February 2021. Lower prices may not only decrease our revenues, but also potentially the amount of oil, natural gas and NGLs that our operators can produce economically.

Oil. The substantial majority of our oil production is sold at prevailing market prices, which fluctuate in response to many factors that are outside of our control. The majority of our oil production is priced at the prevailing market price with the final realized price affected by both quality and location differentials.

The chemical composition of crude oil plays an important role in its refining and subsequent sale as petroleum products. As a result, variations in chemical composition relative to the benchmark crude oil, usually WTI, will result in price adjustments, which are often referred to as quality differentials. The characteristics that most significantly affect quality differentials include the density of the oil, as characterized by its API gravity, and the presence and concentration of impurities, such as sulfur.

Location differentials generally result from transportation costs based on the produced oil’s proximity to consuming and refining markets and major trading points.

Natural Gas. The New York Mercantile Exchange, Inc. (“NYMEX”) price quoted at Henry Hub is a widely used benchmark for the pricing of natural gas in the United States. The actual prices realized from the sale of natural gas differ from the quoted NYMEX price as a result of quality and location differentials.

Quality differentials result from the heating value of natural gas measured in Btus and the presence of impurities, such as hydrogen sulfide, carbon dioxide and nitrogen. Natural gas containing ethane and heavier hydrocarbons has a higher Btu value and will realize a higher volumetric price than natural gas that is predominantly methane, which has a lower Btu value. Natural gas with a higher concentration of impurities will realize a lower price due to the presence of the impurities in the natural gas when sold or the cost of treating the natural gas to meet pipeline quality specifications.

Natural gas, which currently has a limited global transportation system, is subject to price variances based on local supply and demand conditions and the cost to transport natural gas to end-user markets.

NGLs. NGL pricing is generally tied to the price of oil, but varies based on differences in liquid components and location.


Adjusted EBITDA

Adjusted EBITDA is a non-GAAP supplemental financial measure used by our management and by external users of our financial statements such as investors, research analysts and others to assess the financial performance of our assets and their ability to sustain dividends over the long term without regard to financing methods, capital structure or historical cost basis.

We define Adjusted EBITDA as net income (loss) including noncontrolling interests plus (i) interest expense, (ii) provisions for taxes, (iii) depreciation, depletion and amortization, (iv) share-based compensation expense, (v) impairment of oil and natural gas properties, (vii) gains or losses on unsettled derivative instruments, (viii) write off of deferred offering costs, (ix) management fee to affiliates, and (x) one-time transaction costs. Adjusted EBITDA is not a measure determined by GAAP.

This non-GAAP financial measure does not represent and should not be considered an alternative to, or more meaningful than, its most directly comparable GAAP financial measure or any other measure of financial performance presented in accordance with GAAP as measures of our financial performance. Non-GAAP financial measures have important limitations as analytical tools because they exclude some but not all items that affect the most directly comparable GAAP financial measure. Our computation of Adjusted EBITDA may differ from computations of similarly titled measures of other companies.

Sources of Revenue

Our revenues are primarily derived from mineral and royalty payments received from our E&P operators based on the sale of crude oil, natural gas and NGLs production from our interests. Our revenues may vary significantly from period to period because of changes in commodity prices, production mix and volumes of production sold by our E&P operators. For the three months ended March 31, 2022 and 2021, mineral and royalty revenue made up 98% and 97%, respectively, of our total revenue. For the years ended December 31, 2021, 2020 and 2019, mineral and royalty revenue made up 98%, 102% and 85%, respectively, of our total revenue. Mineral and royalty revenues made up more than 100% of our total revenues in 2020 due to the impact of commodity derivative losses on our total revenues. As a result of our royalty income production mix, our income is more sensitive to fluctuations in crude oil prices than it is to fluctuations in natural gas or NGLs prices.

Royalties received related to crude oil sales constituted 76% and 63% of total mineral and royalty revenue for the three months ended March 31, 2022 and 2021, respectively. Royalties received related to crude oil sales constituted 72%, 79% and 85% of total mineral and royalty revenue for the years ended December 31, 2021, 2020 and 2019, respectively. Crude oil, natural gas and NGL prices have historically been volatile, and we expect this volatility to continue.

Additionally, we earn lease bonus income by leasing our mineral interests to exploration and production companies and income from delay rentals and easements. Lease bonus and other income constituted 2% and 3%, respectively, of our total revenue for the three months ended March 31, 2022 and 2021. Lease bonus and other income constituted 2%, 2% and 9%, respectively, of our total revenue for the years ended December 31, 2021, 2020 and 2019.

Further, we earned revenue through the provision of water to various Permian Basin E&P operators produced from our water supply assets. For the years ended December 31, 2021 and 2020, there were no water sales. In April 2020, we entered into an agreement with a third-party water services company to manage our water assets and operations. The agreement was terminated in October 2021 and no longer constitutes a leasing arrangement. Contingent rental income earned under this arrangement was $0 and $202,000, respectively, for the three months ended March 31, 2022 and 2021. Contingent rental income earned under this arrangement was $205,000 and $13,000 for the years ended December 31, 2021 and 2020, respectively. Water sales were $3.5 million for the year ended December 31, 2019.


Principal Components of Our Cost Structure

The following is a description of the principal components of our cost structure. As a mineral and royalty owner, we incur only our proportionate share of production and ad valorem taxes and, in some cases, gathering, processing and transportation costs, which reduce the amount of revenue we recognize. Unlike E&P operators and owners of working interests in oil and gas properties, we are not obligated to fund drilling and completion costs, plugging and abandonment costs or lease operating expenses associated with oil and gas production.

Production and Ad Valorem Taxes

Production taxes are paid at fixed rates on produced crude oil and natural gas based on a percentage of revenues from products sold, established by federal, state or local taxing authorities. The E&P companies who operate on our interests withhold and pay our pro rata share of production taxes on our behalf. We directly pay ad valorem taxes in the counties where our properties are located. Ad valorem taxes are generally based on the appraised value of our crude oil, natural gas and NGLs properties.

Gathering, Processing and Transportation Costs

Gathering, processing and transportation costs are representative of the costs to process and transport our respective volumes to applicable sales points. The terms of the lease with the applicable E&P operator on our interests determine if the operator is able to pass through these costs to us by deducting a pro rata portion of such costs from our production revenues.

General and Administrative

General and administrative expenses consist of costs incurred related to overhead, including executive and other employee compensation and related benefits, office expenses and fees for professional services such as audit, tax, legal and other consulting services. Some of those costs were incurred on our behalf by our general partner and its affiliates and reimbursed by Desert Peak. For example, we reimburse an affiliate of our general partner for personnel costs on our behalf. As a result of becoming a public company, we anticipate incurring incremental general and administrative expenses relating to SEC reporting requirements, including annual and quarterly reports, tax return preparation and dividend expenses, Sarbanes-Oxley Act compliance expenses, expenses associated with listing our common stock, independent auditor fees, legal expenses and investor relations expenses. These incremental general and administrative expenses are not reflected in the historical financial statements or the unaudited pro forma financial statements included as exhibits to the Form 8-K.

Depreciation, Depletion and Amortization

Depreciation, depletion and amortization (“DD&A”) is the systematic expensing of capitalized costs. Under the successful efforts method of accounting, capitalized costs of our proved crude oil, natural gas and NGLs mineral interest properties are depleted on a unit-of-production basis based on proved crude oil, natural gas and NGLs reserve quantities. Our estimates of crude oil, natural gas and NGLs reserves are, by necessity, projections based on geologic and engineering data, and there are uncertainties inherent in the interpretation of such data as well as the projection of future rates of production. Any significant variance in the assumptions could materially affect the estimated quantity of the reserves, which could affect the rate of depletion related to our crude oil, natural gas and NGLs properties. DD&A also includes the expensing of office leasehold costs and water wells and equipment.

Income Tax Expense

We are subject to the Texas margin tax, which is a state franchise tax, and certain state income taxes. We incurred $0.5 million and $81,000 for the three months ended March 31, 2022 and 2021, respectively, for state income taxes. For the years ended December 31, 2021, 2020 and 2019, we incurred $0.6 million, $38,000 and $0.2 million, respectively, for state franchise tax payable to the Texas Comptroller of Public Accounts and other certain state income taxes. Desert Peak did not record a provision for U.S. federal income taxes because the partners reported their respective share of our income or loss on their income tax returns. Following the events comprising the Merger Transactions described in the Form 8-K, we will be subject to U.S. federal income taxes as a corporation. We will also continue to be subject to the Texas margin tax as a corporation.


Factors Affecting the Comparability of Our Financial Results

Our future results of operations may not be comparable to our historical results of operations for the periods presented, primarily for the reasons described below.

Surface Rights

The historical consolidated financial statements included as exhibits to the Form 8-K are based on our financial statements prior to the Merger Transactions. The assets to be acquired in connection with the Merger Transactions will not include KMF’s surface rights, which generate revenue from the sale of water, payments for rights-of-way and other rights associated with the ownership of the surface acreage, which are included in our historical financial statements but will be retained by KMF following the closing of the Merger Transactions. As a result, the historical consolidated financial data may not give you an accurate indication of what the actual results would have been if the Merger Transactions had been completed at the beginning of the periods presented or of what our future results of operations are likely to be.

Management Fees

KMF incurred and paid annual fees under an investment management agreement with Kimmeridge Energy Management Company, LLC, an affiliate of Kimmeridge, of which Noam Lockshin, a Director Nominee, is a managing member. Fees incurred under the agreement totaled approximately $1.9 million for the three months ended March 31, 2022 and 2021. Fees incurred under the agreement totaled approximately $7.5 million for the years ended December 31, 2021, 2020 and 2019, respectively. We will not incur future expense under the agreement upon completion of the Merger Transactions. Additionally, certain other expenses associated with the limited partnership structure of Desert Peak will not be incurred by us in future periods.

Acquisitions

Our historical financial statements as of and for the years ended December 31, 2020 and 2019 or the three months ended March 31, 2021 do not include the results of operations for the assets acquired in the Chambers Acquisition, Rock Ridge Acquisition and Source Acquisition. Our historical financial statements as of and for the year ended, subsequent to the respective acquisition dates, December 31, 2021 include the results of operations for the assets acquired in the Chambers Acquisition, Rock Ridge Acquisition and Source Acquisition. As a result, our historical financial data as of and for the years ended December 31, 2020 and 2019 and for the year ended December 31, 2021 does not give an accurate indication of what the actual results would have been if such acquisitions had been completed at the beginning of the periods presented or of what our future results are likely to be. For additional information, please see the unaudited pro forma condensed combined financial statements and related notes included as Exhibit 99.6 to the Form 8-K.

In addition, we plan to pursue potential accretive acquisitions of additional mineral and royalty interests. We believe we will be well positioned to acquire such assets and, should such opportunities arise, identifying and executing acquisitions will be a key part of our strategy. However, if we are unable to make acquisitions on economically acceptable terms, our future growth may be limited, and any acquisitions we may make may reduce, rather than increase, our cash flows and ability to pay dividends to stockholders.

Debt and Interest Expense

We had no debt until September 26, 2019, when we established our original credit facility. As a public company, we may finance a portion of our acquisitions with borrowings under our revolving credit facility. As a result, we will incur interest expense that is affected by both fluctuations in interest rates and our financing decisions.

Public Company Expenses

Following the closing of the Merger Transactions, we anticipate incurring incremental general and administrative expenses as a result of Kimmeridge no longer providing services to us and as a result of operating as a publicly traded company, such as expenses associated with SEC reporting requirements, including annual and


quarterly reports, Sarbanes-Oxley Act compliance expenses, expenses associated with listing our common stock, independent auditor fees, independent reserve engineer fees, legal fees, investor relations expenses, registrar and transfer agent fees, director and officer insurance expenses and director and officer compensation expenses. These incremental general and administrative expenses are not reflected in our historical financial statements. Additionally, in anticipation of the Merger Transactions, we have hired additional employees, including accounting, engineering and land personnel, in order to prepare for the requirements of being a publicly traded company.

Income Taxes

We will be subject to U.S. federal and state income taxes as a corporation. KMF was generally not subject to U.S. federal income tax at the entity level. As such, our financial statements do not contain a provision for U.S. federal income taxes. The only tax expense that appeared in our financial statements was the Texas margin tax and certain state income taxes, to which we will continue to be subject as a corporation.

Results of Operations

Three Months Ended March 31, 2022 Compared to the Three Months Ended March 31, 2021

Consolidated Results

The following table summarizes our consolidated revenue and expenses and production data for the three months ended March 31, 2022 and 2021 (in thousands):

 

     For the three months
ended March 31,
 
     2022      2021  

Statement of Operations Data:

     

Revenue:

     

Total Revenue

   $ 66,363      $ 17,049  

Operating Expenses:

     

Management fees to affiliates

   $ 1,870      $ 1,870  

Depreciation, depletion and amortization

     15,385        6,865  

General and administrative

     3,983        703  

General and administrative—affiliates

     80        1,638  

Severance and ad valorem taxes

     3,725        1,110  

Total operating expenses

     25,043        12,186  
  

 

 

    

 

 

 

Net income from operations

     41,320        4,863  
  

 

 

    

 

 

 

Interest expense (net)(1)

     (1,168      (306

Commodity derivative losses

     (1,114      —    

Net income before income tax expense

     39,038        4,557  

Income tax expense

     (516      (81
  

 

 

    

 

 

 

Net income including noncontrolling interests

     38,522        4,476  

Net income attributable to noncontrolling interests

     19,242        —    
  

 

 

    

 

 

 

Net income

   $ 19,280      $ 4,476  
  

 

 

    

 

 

 

 

     For the three months
ended March 31,
 
     2022      2021  

Production Data:

     

Crude oil (Mbbls)

     535        189  

Natural gas (Mmcf)

     1,694        1,025  

NGLs (Mbbls)

     207        79  
  

 

 

    

 

 

 

Total (BOE)(6:1)

     1,025        440  
  

 

 

    

 

 

 

Average daily production (BOE/d)(6:1)

     11,387        4,885  

Average Realized Prices:

     

Crude oil (per Bbl)

   $ 92.04      $ 54.81  

Natural gas (per Mcf)

   $ 4.63      $ 3.66  

NGLs (per Bbl)

   $ 37.81      $ 29.29  

Combined (per BOE)

   $ 63.38      $ 37.42  

Average Realized Prices After Effects of Derivative Settlements:

     

Crude oil (per Bbl)

   $ 92.04      $ 54.81  

Natural gas (per Mcf)

   $ 4.63      $ 3.66  

NGLs (per Bbl)

   $ 37.81      $ 29.29  

Combined (per BOE)

   $ 63.38      $ 37.42  

 

(1)

Interest expense is presented net of interest income.


Revenue

Our consolidated revenues for the three months ended March 31, 2022 totaled $66.4 million as compared to $17.0 million for the three months ended March 31, 2021, an increase of 289%. The increase in revenues was due to an increase of $48.6 million in mineral and royalty revenue and an increase of $0.8 million in lease bonus and other income. The increase in mineral and royalty revenue was primarily due to increased commodity prices, production volumes from our acquisitions of additional mineral and royalty interests, and production volumes from existing interests. Lease bonus and other income is subject to significant variability from period to period based on the particular tracts of land that become available for releasing. In April 2020, we entered into an agreement with a third-party water services company to manage our water assets and operations. The agreement was terminated in October 2021 and no longer constitutes a leasing arrangement. Contingent rental income earned under this arrangement was $202,000 for the three months ended March 31, 2021. There was no income earned under this arrangement for the three months ended March 31, 2022.

Our Oil and Gas Producing Activities segment generated 100% and 99% of our total revenues for the three months ended March 31, 2022 and 2021, respectively, with our Water Service Operations segment contributing a de minimis amount of our total revenues for the three months ended March 31, 2022.

Oil revenue for the three months ended March 31, 2022 was $49.3 million as compared to $10.4 million for the three months ended March 31, 2021, an increase of $38.9 million. An increase of $37.23/Bbl in our average price received for oil production, from $54.81/Bbl for the three months ended March 31, 2021 to $92.04/Bbl for the three months ended March 31, 2022, accounted for an approximate $19.9 million increase in our year-over-year oil revenue. Additionally, we realized a $19.0 million increase in year-over-year oil revenue due to a 183% increase in oil production volumes, which increased from 189 Mbbls for the three months ended March 31, 2021 to 535 Mbbls for the three months ended March 31, 2022.

Natural gas revenue for the three months ended March 31, 2022 was $7.8 million as compared to $3.7 million for the three months ended March 31, 2021, an increase of $4.1 million. An increase of $0.97/Mcf in our average price received for gas production, from $3.66/Mcf for the three months ended March 31, 2021 to $4.63/Mcf for the three months ended March 31, 2022, accounted for an approximate $1.7 million increase in our year-over-year gas revenue. Additionally, we realized a $2.4 million increase in year-over-year gas revenue due to a 65% increase in gas production volumes, which increased from 1,025 MMcf for the three months ended March 31, 2021 to 1,694 MMcf for the three months ended March 31, 2022.

NGLs revenue for the three months ended March 31, 2022 was $7.8 million as compared to $2.3 million for the three months ended March 31, 2021, an increase of $5.5 million. An increase of $8.52/Bbl in our average price received for NGLs production, from $29.29/Bbl for the three months ended March 31, 2021 to $37.81/Bbl for the three months ended March 31, 2022, accounted for an approximate $1.8 million increase in our year-over-year NGLs revenue. Additionally, we realized a $3.7 million increase in year-over-year NGLs revenue due to a 161% increase in NGLs production volumes, which increased from 79 MBbls for the three months ended March 31, 2021 to 207 MBbls for the three months ended March 31, 2022.

Lease bonus revenue for the three months ended March 31, 2022 was $1.2 million as compared to $41,000 for the three months ended March 31, 2021. When we lease our acreage to an E&P operator, we generally receive a lease bonus payment at the time a lease is executed. These bonus payments are subject to significant variability from period to period based on the particular tracts of land that become available for releasing. Other revenues for the three months ended March 31, 2022 were $180,000 as compared to $555,000 for the three months ended March 31, 2021, which include payments for right-of-way and surface damages, which are also subject to significant variability.


Operating Expenses

Management fees to affiliates expense remained consistent at $1.9 million for the three months ended March 31, 2022 and 2021.

Depreciation, depletion and amortization expense was $15.4 million for the three months ended March 31, 2022 as compared to $6.9 million for the three months ended March 31, 2021, an increase of $8.5 million, or 124%. The increase was primarily due to 133% increase in year-over-year production offset by a lower depletion rate, which decreased from $15.28/Boe for the three months ended March 31, 2021 to $14.87/Boe for the three months ended March 31, 2022.

General and administrative expense was $4.0 million for the three months ended March 31, 2022 as compared to $703,000 for the three months ended March 31, 2021, an increase of $3.3 million, or 467%. The increase was primarily due to increased personnel costs captured here for the three months ended March 31, 2022, public transaction costs related to the Merger Transactions, and professional services costs noted below.

General and administrative—affiliates expense was $80,000 for the three months ended March 31, 2022 as compared to $1.6 million for the three months ended March 31, 2021, a decrease of $1.5 million, or 95%. The decrease was primarily a result of decreased reimbursement to our general partner for services provided on our behalf, including personnel costs and costs relating to the performance of land and administrative services in respect of our acquisition of mineral and royalty interests. These costs were captured in the General and administrative expense line item for the first three months of 2022.

On a combined basis, the General and administrative expense and General and administrative expense— affiliates expense was $4.1 million for the three months ended March 31, 2022 as compared to $2.3 million for the three months ended March 31, 2021, an increase of $1.8 million, or 74%, primarily due to $1.2 million of transaction costs related to the Merger Transactions, $0.2 million of employee compensation due in increased headcount, $0.1 million of additional rent expense, and $0.3 million of other professional services.

Severance and ad valorem taxes was $3.7 million for the three months ended March 31, 2022 as compared to $1.1 million for the three months ended March 31, 2021, an increase of $2.6 million or 236%. The increase was primarily due to an increase in severance taxes in conjunction with the year-over-year increase in commodity prices and increased production volumes from our acquisitions of additional mineral and royalty interests and existing interests.

Interest expense of approximately $1.2 million and $0.3 million during the three months ended March 31, 2022 and 2021, respectively, relates to interest incurred on borrowings under our revolving credit facility. The increase in interest expense was due to higher average borrowings under the facility during the three months ended March 31, 2022 as compared to March 31, 2021 due to funding acquisitions and distributions to the members of DPM HoldCo in the second half of 2021.

Commodity derivatives losses totaled $1.1 million for the three months ended March 31, 2022, whereas there were no derivatives gains or losses for the three months ended March 31, 2021. In 2022, we entered into oil and gas fixed price swaps to manage commodity price risks associated with our production.

Income tax expense primarily relates to state franchise taxes and certain state income taxes, and totaled approximately $0.5 million and $81,000 for the three months ended March 31, 2022 and 2021, respectively.


Segment Results

The following table sets forth certain financial information with respect to our reportable segments (in thousands):

 

     For the three months ended March 31, 2022  
     Oil and Gas
Producing
Activities
     Water
Service
Operations
     Partnership      Consolidated
Total
 

Revenues

   $ 66,261      $ 102      $ —        $ 66,363  

Depreciation, depletion and amortization

     15,313        72        —          15,385  

Income tax expense

     (491      —          (25      (516

Interest expense

     (1,176      —          —          (1,176

Segment profit (loss)

     40,446        21        (1,953      38,514  

Total assets as of March 31, 2022

     1,199,215        3,250        2,120        1,204,585  

Capital expenditures, including mineral acquisitions

     676        —          —          676  

A reconciliation of segment profit to net income is as follows:

 

Segment profit

   $ 38,514  

Interest income

     8  

Net income attributable to noncontrolling interests

     19,242  

Net income attributable to partners

     19,280  

 

     For the three months ended March 31, 2021  
     Oil and
Gas
Producing
Activities
     Water
Service
Operations
     Partnership      Consolidated
Total
 

Revenues

   $ 16,847      $ 202      $ —        $ 17,049  

Depreciation, depletion and amortization

     6,793        72        —          6,865  

Income tax expense

     (81      —          —          (81

Interest expense

     (307      —          —          (307

Segment profit (loss)

     6,259        130        (1,914      4,475  

Total assets as of March 31, 2021

     588,979        3,529        2,143        594,651  

Capital expenditures (reimbursements), including mineral acquisitions

     (105      —          —          (105

A reconciliation of segment profit to net income is as follows:

 

Segment profit

   $ 4,475  

Interest income

     1  

Net income attributable to noncontrolling interests

     —    

Net income attributable to partners

     4,476  

Oil and Gas Producing Activities

Oil revenue for the three months ended March 31, 2022 was $49.3 million as compared to $10.4 million for the three months ended March 31, 2021, an increase of $38.9 million. An increase of $37.23/Bbl in our average price received for oil production, from $54.81/Bbl for the three months ended March 31, 2021 to $92.04/Bbl for the three months ended March 31, 2022, accounted for an approximate $19.9 million increase in our year-over-year oil revenue. Additionally, we realized a $19.0 million increase in year-over-year oil revenue due to a 183% increase in oil production volumes, which increased from 189 Mbbls for the three months ended March 31, 2021 to 535 Mbbls for the three months ended March 31, 2022.

Natural gas revenue for the three months ended March 31, 2022 was $7.8 million as compared to $3.7 million for the three months ended March 31, 2021, an increase of $4.1 million. An increase of $0.97/Mcf in our average price received for gas production, from $3.66/Mcf for the three months ended March 31, 2021 to $4.63/Mcf for the three months ended March 31, 2022, accounted for an approximate $1.7 million increase in our year-over-year gas revenue. Additionally, we realized a $2.4 million increase in year-over-year gas revenue due to a 65% increase in gas production volumes, which increased from 1,025 MMcf for the three months ended March 31, 2021 to 1,694 MMcf for the three months ended March 31, 2022.


NGLs revenue for the three months ended March 31, 2022 was $7.8 million as compared to $2.3 million for the three months ended March 31, 2021, an increase of $5.5 million. An increase of $8.52/Bbl in our average price received for NGLs production, from $29.29/Bbl for the three months ended March 31, 2021 to $37.81/Bbl for the three months ended March 31, 2022, accounted for an approximate $1.8 million increase in our year-over-year NGLs revenue. Additionally, we realized a $3.7 million increase in year-over-year NGLs revenue due to a 161% increase in NGLs production volumes, which increased from 79 MBbls for the three months ended March 31, 2021 to 207 MBbls for the three months ended March 31, 2022.

The following table presents the breakdown of our royalty revenues attributable to sales of crude oil, natural gas and NGLs totaling approximately $65.0 million and $16.5 million for the three months ended March 31, 2022 and 2021, respectively:

 

     Three months ended
March 31,
 
     2022     2021  

Royalty Revenue

    

Crude oil sales

     76     63

Natural gas sales

     12     23

NGLs sales

     12     14
  

 

 

   

 

 

 

Total Royalty Revenue

     100     100
  

 

 

   

 

 

 

Our oil and gas producing activities segment revenues are primarily a function of crude oil, natural gas, and NGLs production volumes sold and average prices received for those volumes, each of which can vary significantly from period to period. Despite such variability, we expect our royalty revenues to continue to be primarily attributable to crude oil sales.

Lease bonus revenue for the three months ended March 31, 2022 was $1.2 million as compared to $41,000 for the three months ended March 31, 2021. When we lease our acreage to an E&P operator, we generally receive a lease bonus payment at the time a lease is executed. These bonus payments are subject to significant variability from period to period based on the particular tracts of land that become available for releasing. Other revenues for the three months ended March 31, 2022 were $180,000 as compared to $555,000 for the three months ended March 31, 2021, which include payments for right-of-way and surface damages, which are also subject to significant variability.

Commodity derivatives losses totaled $1.1 million for the three months ended March 31, 2022, whereas there were no derivatives gains or losses for the three months ended March 31, 2021. In 2022, we entered into oil and gas fixed price swaps to manage commodity price risks associated with our production.

Operating expenses for the oil and gas producing activities segment totaled approximately $23.0 million for the three months ended March 31, 2022, and consisted primarily of depreciation, depletion and amortization of $15.3 million, employee compensation and benefits of $1.9 million, general and administrative of $2.1 million, and severance and ad valorem taxes of $3.7 million.

Operating expenses for the oil and gas producing activities segment totaled approximately $10.2 million for the three months ended March 31, 2021, and consisted primarily of depreciation, depletion and amortization of $6.8 million, production and ad valorem taxes of $1.1 million, employee compensation and benefits of $1.6 million, and general and administrative of $0.7 million.

Income tax expense attributable to the oil and gas producing activities segment primarily relate to state franchise taxes and state income taxes, and totaled approximately $0.5 million and $81,000 for the three months ended March 31, 2022 and 2021, respectively.


Water Service Operations

In April 2020, we entered into an agreement with a third-party water services company to manage our water assets and operations. The agreement constitutes a leasing arrangement under which we are a lessor. Under the terms of the agreement, we are not entitled to any income until the lessee has completed a water sale and received payment from its customer. Contingent rental income earned under this arrangement was $0.2 million for the three months ended March 31, 2021. There was no income earned under this arrangement for the three months ended March 31, 2022. In October 2021, the agreement was terminated.

Operating expenses totaled approximately $81,000 and $72,000 for the three months ended March 31, 2022 and 2021, respectively, and consisted primarily of depreciation, depletion and amortization and employee compensation.

Year Ended December 31, 2021 Compared to the Year Ended December 31, 2020

Consolidated Results

The following table summarizes our consolidated revenue and expenses and production data for the years ended December 31, 2021 and 2020 (in thousands):

 

     For the year ended
December 31,
 
     2021      2020  

Statement of Operations Data:

     

Revenue:

     

Total Revenue

   $ 120,588      $ 43,126  

Operating Expenses:

     

Management fees to affiliates

   $ 7,480      $ 7,480  

Depreciation, depletion and amortization

     40,906        32,049  

General and administrative

     4,143        4,981  

General and administrative—affiliates

     8,855        4,407  

Impairment of oil and natural gas properties

     —          812  

Severance and ad valorem taxes

     6,858        3,151  

Deferred offering costs write off

     2,396        2,747  

Bad debt recovered

     —          (251

Gain on sale of other property

     —          (42

Total operating expenses

     70,638        55,334  
  

 

 

    

 

 

 

Net income (loss) from operations

     49,950        (12,208
  

 

 

    

 

 

 

Interest expense (net)(1)

     (1,893      (1,968

Net income (loss) before income tax expense

     48,057        (14,176

Income tax expense

     (562      (38
  

 

 

    

 

 

 

Net income (loss) including noncontrolling interests

     47,495        (14,214

Net income attributable to noncontrolling interests

     18,781        —    
  

 

 

    

 

 

 

Net income (loss) attributable to partners

   $ 28,714      $ (14,214
  

 

 

    

 

 

 

 

     For the year ended
December 31,
 
     2021      2020  

Production Data:

     

Crude oil (Mbbls)

     1,261        933  

Natural gas (Mmcf)

     4,746        4,134  

NGLs (Mbbls)

     499        488  
  

 

 

    

 

 

 

Total (BOE)(6:1)

     2,551        2,110  
  

 

 

    

 

 

 

Average daily production (BOE/d)(6:1)

     6,989        5,764  

Average Realized Prices:

     

Crude oil (per Bbl)

   $ 67.29      $ 37.40  

Natural gas (per Mcf)

   $ 3.61      $ 1.03  

NGLs (per Bbl)

   $ 33.22      $ 10.32  

Combined (per BOE)

   $ 46.47      $ 20.95  

Average Realized Prices After Effects of Derivative Settlements:

     

Crude oil (per Bbl)

   $ 67.29      $ 34.64  

Natural gas (per Mcf)

   $ 3.61      $ 1.03  

NGLs (per Bbl)

   $ 33.22      $ 10.32  

Combined (per BOE)

   $ 46.47      $ 19.73  

 

(1)

Interest expense is presented net of interest income.


Revenue

Our consolidated revenues for the year ended December 31, 2021 totaled $120.6 million as compared to $43.1 million for the year ended December 31, 2020, an increase of 180%. The increase in revenues was due to an increase of $74.4 million in mineral and royalty revenue, an increase of $0.5 million in lease bonus and other income, and a commodity derivative loss of $2.6 million in 2020. The increase in mineral and royalty revenue was primarily due to increased commodity prices, increased production volumes from our acquisitions of additional mineral and royalty interests, and increased production volumes from existing interests. Lease bonus and other income is subject to significant variability from period to period based on the particular tracts of land that become available for releasing. In April 2020, we entered into an agreement with a third-party water services company to manage our water assets and operations. Contingent rental income earned under this arrangement was $0.2 million and $13,000 for the years ended December 30, 2021 and 2020, respectively. The agreement was terminated in October 2021.

Our Oil and Gas Producing Activities segment generated approximately 100% of our total revenues for the years ended December 31, 2021 and 2020, with our Water Service Operations segment contributing a de minimis amount of our total revenues for the years ended December 31, 2021 and 2020.

Oil revenue for the year ended December 31, 2021 was $84.8 million as compared to $34.9 million for the year ended December 31, 2020, an increase of $49.9 million. An increase of $29.89/Bbl in our average price received for oil production, from $37.40/Bbl for the year ended December 31, 2020 to $67.29/Bbl for the year ended December 31, 2021, accounted for an approximate $37.7 million increase in our year-over-year oil revenue. Additionally, we realized a $12.2 million increase in year-over-year oil revenue due to a 35% increase in oil production volumes, which increased from 933 Mbbls for the year ended December 31, 2020 to 1,261 Mbbls for the year ended December 31, 2021.

Natural gas revenue for the year ended December 31, 2021 was $17.1 million as compared to $4.3 million for the year ended December 31, 2020, an increase of $12.8 million. An increase of $2.58/Mcf in our average price received for gas production, from $1.03/Mcf for the year ended December 31, 2020 to $3.61/Mcf for the year ended December 31, 2021, accounted for an approximate $12.2 million increase in our year-over-year gas revenue. Additionally, we realized a $0.6 million increase in year-over-year gas revenue due to a 15% increase in gas production volumes, which increased from 4,134 MMcf for the year ended December 31, 2020 to 4,746 MMcf for the year ended December 31, 2021.

NGLs revenue for the year ended December 31, 2021 was $16.6 million as compared to $5.0 million for the year ended December 31, 2020, an increase of $11.6 million. An increase of $22.90/Bbl in our average price received for NGLs production, from $10.32/Bbl for the year ended December 31, 2020 to $33.22/Bbl for the year ended December 31, 2021, accounted for an approximate $11.5 million increase in our year-over-year NGLs revenue, and a $0.1 million increase in year-over-year NGLs revenue due to a 2% increase in NGLs production volumes, which increased from 488 MBbls for the year ended December 31, 2020 to 499 MBbls for the year ended December 31, 2021.

Lease bonus revenue for the year ended December 31, 2021 was $1.2 million as compared to $0.7 million for the year ended December 31, 2020. When we lease our acreage to an E&P operator, we generally receive a lease bonus payment at the time a lease is executed. These bonus payments are subject to significant variability from period to period based on the particular tracts of land that become available for releasing. Other revenues for the years ended December 31, 2021 and 2020, were $0.8 million, which include payments for right-of-way and surface damages, which are also subject to significant variability.


Operating Expenses

Management fees to affiliates expense remained consistent at $7.5 million for the years ended December 31, 2021 and 2020.

Depreciation, depletion and amortization expense was $40.9 million for the year ended December 31, 2021 as compared to $32.0 million for the year ended December 31, 2020, an increase of $8.9 million, or 28%. The increase was primarily due to our 21% increase in year-over-year production as well as a higher depletion rate, which increased from $14.90/Boe for the year ended December 31, 2020 to $15.80/Boe for the year ended December 31, 2021 due to reserves increasing at a slower rate than our net depletable capitalized costs from December 31, 2020 to December 31, 2021.

General and administrative expense was $4.1 million for the year ended December 31, 2021 as compared to $5.0 million for the year ended December 31, 2020, a decrease of $0.9 million, or 17%. The decrease was primarily due to decreased personnel costs captured here for the first half of 2020 as noted below and professional services costs.

General and administrative—affiliates expense was $8.9 million for the year ended December 31, 2021 as compared to $4.4 million for the year ended December 31, 2020, an increase of $4.5 million, or 101%. The increase was primarily a result of increased reimbursement to our general partner for services provided on our behalf, including personnel costs.. These costs were captured in the general and administrative expense line item for the first half of 2020.

On a combined basis, the general and administrative expense and general and administrative expense— affiliates expense was $13.0 million for the year ended December 31, 2021 as compared to $9.4 million for the year ended December 31, 2020, an increase of $3.6 million, or 38%. The increase was a result of increased reimbursement to our general partner for services provided on our behalf, including personnel costs.

Impairment of oil and gas properties of approximately $0.8 million for the year ended December 31, 2020 was recognized in connection with capitalized acquisition costs for a prospective mineral interest acquisition that we did not complete. We did not recognize impairment of oil and gas properties for the year ended December 31, 2021.

Severance and ad valorem taxes was $6.9 million for the year ended December 31, 2021 as compared to $3.2 million for the year ended December 31, 2020, an increase of $3.7 million or 118%. The increase was primarily due to an increase in severance taxes in conjunction with the year-over-year increase in commodity prices and increased production volumes from our acquisitions of additional mineral and royalty interests.

During the years ended December 31, 2021 and 2020, we recognized approximately $2.4 million and $2.7 million of expense, respectively, in connection with the cancelation of an initial public offering.

During the year ended December 31, 2020, we reversed approximately ($0.3) million of bad debt expense due to the collection of accounts receivable of KMF Water for which an allowance had previously been established. No such charges or benefits were recorded during the year ended December 31, 2021.

Interest expense of approximately $1.9 million and $2.0 million during the years ended December 31, 2021 and 2020, respectively, relates to interest incurred on borrowings under our revolving credit facility. The decrease in interest expense was due to lower average borrowings under the facility during the majority of the year ended December 31, 2021 as we continued to make payments to reduce the outstanding balance throughout 2020 and into 2021. During the second half of 2021, we funded acquisitions and the distributions to the members of DPM HoldCo with increased borrowings.

Income tax expense primarily relates to state franchise taxes and totaled approximately $0.6 million and $38,000 for the years ended December 31, 2021 and 2020, respectively.


Segment Results

The following table sets forth certain financial information with respect to our reportable segments (in thousands):

 

     For the year ended December 31, 2021  
     Oil and Gas
Producing
Activities
     Water
Service
Operations
     Partnership      Consolidated
Total
 

Revenues

   $ 120,362      $ 226      $ —        $ 120,588  

Depreciation, depletion and amortization

     40,619        287        —          40,906  

Income tax expense

     (555      —          (7      (562

Interest expense

     (1,918      —          —          (1,918

Segment profit (loss)

     55,272        32        (7,834      47,470  

Total assets as of December 31, 2021

     1,195,520        3,314        4,020        1,202,854  

Capital expenditures, including mineral acquisitions

     38,470        —          —          38,470  

A reconciliation of segment profit (loss) to net income is as follows:

 

Segment profit

   $ 47,470  

Interest income

     25  

Net income attributable to noncontrolling interests

     18,781  

Net income attributable to partners

     28,714  

 

     For the year ended December 31, 2020  
     Oil and
Gas
Producing
Activities
     Water
Service
Operations
     Partnership      Consolidated
Total
 

Revenues

   $ 43,113      $ 13      $ —        $ 43,126  

Depreciation, depletion and amortization

     31,746        303        —          32,049  

Income tax expense

     (38      —          —          (38

Interest expense

     (2,021      —          —          (2,021

Segment loss

     (6,253      (165      (7,849      (14,267

Total assets as of December 31, 2020

     591,140        3,602        3,886        598,628  

Capital expenditures, including mineral acquisitions

     35,836        —          —          35,836  

A reconciliation of segment profit (loss) to net income is as follows:

 

Segment loss

   $ (14,267

Interest income

     53  

Net loss

     (14,214

Oil and Gas Producing Activities

Oil revenue for the year ended December 31, 2021 was $84.8 million as compared to $34.9 million for the year ended December 31, 2020, an increase of $49.9 million. An increase of $29.89/Bbl in our average price received for oil production, from $37.40/Bbl for the year ended December 31, 2020 to $67.29/Bbl for the year ended December 31, 2021, accounted for an approximate $37.7 million increase in our year-over-year oil revenue. Additionally, we realized a $12.2 million increase in year-over-year oil revenue due to a 35% increase in oil production volumes, which increased from 933 Mbbls for the year ended December 31, 2020 to 1,261 Mbbls for the year ended December 31, 2021.

Natural gas revenue for the year ended December 31, 2021 was $17.1 million as compared to $4.3 million for the year ended December 31, 2020, an increase of $12.8 million. An increase of $2.58/Mcf in our average price received for gas production, from $1.03/Mcf for the year ended December 31, 2020 to $3.61/Mcf for the year ended December 31, 2021, accounted for an approximate $12.2 million increase in our year-over-year gas revenue. Additionally, we realized a $0.6 million increase in year-over-year gas revenue due to a 15% increase in gas production volumes, which increased from 4,134 MMcf for the year ended December 31, 2020 to 4,746 MMcf for the year ended December 31, 2021.


NGLs revenue for the year ended December 31, 2021 was $16.6 million as compared to $5.0 million for the year ended December 31, 2020, an increase of $11.6 million. An increase of $22.90/Bbl in our average price received for NGLs production, from $10.32/Bbl for the year ended December 31, 2020 to $33.22/Bbl for the year ended December 31, 2021, accounted for an approximate $11.5 million increase in our year-over-year NGLs revenue, and a $0.1 million increase in year-over-year NGLs revenue due to a 2% increase in NGLs production volumes, which increased from 488 MBbls for the year ended December 31, 2020 to 499 MBbls for the year ended December 31, 2021.

The following table presents the breakdown of our royalty revenues attributable to sales of crude oil, natural gas and NGLs totaling approximately $118.5 million and $44.2 million for the year ended December 31, 2021 and 2020, respectively:

 

     Year ended
December 31,
 
     2021     2020  

Royalty Revenue

    

Crude oil sales

     72     79

Natural gas sales

     14     10

NGLs sales

     14     11
  

 

 

   

 

 

 

Total Royalty Revenue

     100     100
  

 

 

   

 

 

 

Our oil and gas producing activities segment revenues are primarily a function of crude oil, natural gas, and NGLs production volumes sold and average prices received for those volumes, each of which can vary significantly from period to period. Despite such variability, we expect our royalty revenues to continue to be primarily attributable to crude oil sales.

Lease bonus revenue for the year ended December 31, 2021 was $1.2 million as compared to $0.7 million for the year ended December 31, 2020. When we lease our acreage to an E&P operator, we generally receive a lease bonus payment at the time a lease is executed. These bonus payments are subject to significant variability from period to period based on the particular tracts of land that become available for releasing. Other revenues for the years ended December 31, 2021 and 2020, were $0.8 million, which include payments for right-of-way and surface damages, which are also subject to significant variability.

Commodity derivatives losses totaled $2.6 million for the year ended December 31, 2020, whereas there were no derivatives gains or losses for the year ended December 31, 2021. In 2020, we entered into oil fixed price swaps and oil basis swaps to manage commodity price risks associated with our production. In October 2020, we terminated all of our outstanding oil and basis swap derivative contracts. We were not party to any derivative contracts as of December 31, 2021 and 2020.

Operating expenses for the oil and gas producing activities segment totaled approximately $62.5 million for the year ended December 31, 2021, and consisted primarily of depreciation, depletion and amortization of $40.6 million, employee compensation and benefits of $8.6 million, general and administrative of $4.0 million, production and ad valorem taxes of $6.9 million, and write off of deferred offering costs of $2.4 million.

Operating expenses for the oil and gas producing activities segment totaled approximately $47.3 million for the year ended December 31, 2020, and consisted primarily of depreciation, depletion and amortization of $31.7 million, employee compensation and benefits of $6.1 million, general and administrative of $2.8 million, write off of deferred offering costs of $2.7 million, impairment of unproved oil and gas properties of $0.8 million, and production and ad valorem taxes of $3.2 million.

Income tax expense attributable to the oil and gas producing activities segment primarily relate to state franchise taxes, and totaled approximately $0.6 million and $38,000 for the year ended December 31, 2021 and 2020, respectively.


Water Service Operations

For the year ended December 31, 2021 and 2020, there were no water sales. In April 2020, we entered into an agreement with a third-party water services company to manage our water assets and operations. The agreement constitutes a leasing arrangement under which we are a lessor. Under the terms of the agreement, we are not entitled to any income until the lessee has completed a water sale and received payment from its customer. Contingent rental income earned under this arrangement was $0.2 million and $13,000 for the years ended December 31, 2021 and 2020, respectively. In October 2021, the agreement was terminated.

Operating expenses totaled approximately $0.3 million and $0.2 million for the years ended December 31, 2021 and 2020, respectively, and consisted primarily of depreciation, depletion and amortization and employee compensation.

Year Ended December 31, 2020 Compared to the Year Ended December 31, 2019

Consolidated Results

The following table summarizes our consolidated revenue and expenses and production data for the years ended December 31, 2020 and 2019 (in thousands):

 

     For the year ended
December 31,
 
     2020      2019  

Statement of Operations Data:

     

Revenue:

     

Total Revenue

   $ 43,126      $ 59,680  

Operating Expenses:

     

Management fees to affiliates

   $ 7,480      $ 7,480  

Depreciation, depletion and amortization

     32,049        26,201  

General and administrative

     4,981        2,349  

General and administrative—affiliates

     4,407        8,167  

Impairment of oil and natural gas properties

     812        —    

Production costs, ad valorem taxes and operating expense

     3,151        5,249  

Deferred offering costs write off

     2,747        —    

Bad debt expense (recovered)

     (251      405  

Gain on sale of other property

     (42      —    
  

 

 

    

 

 

 

Total operating expenses

     55,334        49,851  
  

 

 

    

 

 

 

Net income (loss) from operations

     (12,208      9,829  

Interest expense (net)(1)

     (1,968      (868

Net income (loss) before income tax expense

     (14,176      8,961  

Income tax expense

     (38      (171
  

 

 

    

 

 

 

Net income (loss)

   $ (14,214    $ 8,790  
  

 

 

    

 

 

 

 

     For the year ended
December 31,
 
     2020      2019  

Production Data:

     

Crude oil (Mbbls)

     933        816  

Natural gas (Mmcf)

     4,134        3,237  

NGLs (Mbbls)

     488        393  
  

 

 

    

 

 

 

Total (BOE)(6:1)

     2,110        1,749  
  

 

 

    

 

 

 

Average daily production (BOE/d)(6:1)

     5,764        4,793  

Average Realized Prices:

     

Crude oil (per Bbl)

   $ 37.40      $ 52.90  

Natural gas (per Mcf)

   $ 1.03      $ 0.74  

NGLs (per Bbl)

   $ 10.32      $ 13.48  

Combined (per BOE)

   $ 20.95      $ 29.09  

Average Realized Prices After Effects of Derivative Settlements:

     

Crude oil (per Bbl)

   $ 34.64      $ 52.90  

Natural gas (per Mcf)

   $ 1.03      $ 0.74  

NGLs (per Bbl)

   $ 10.32      $ 13.48  

Combined (per BOE)

   $ 19.73      $ 29.09  

 

(1)

Interest expense is presented net of interest income.


Revenue

Our consolidated revenues for the year ended December 31, 2020 totaled $43.1 million as compared to $59.7 million for the year ended December 31, 2019, a decrease of 28%. The decrease in revenues was due to a decrease of $6.7 million in mineral and royalty revenue, a decrease of $3.8 million in lease bonus and other income, a $3.5 million decrease in water sales revenue, and a commodity derivative loss of $2.6 million in 2020. The decrease in mineral and royalty revenue was primarily due to decreased commodity prices. Lease bonus and other income is subject to significant variability from period to period based on the particular tracts of land that become available for releasing. For the year ended December 31, 2020, there were no water sales, whereas we generated total water revenues of $3.5 million for the year ended December 31, 2019. In April 2020, we entered into an agreement with a third-party water services company to manage our water assets and operations. Contingent rental income earned under this arrangement was $13,000 for the year ended December 31, 2020, as compared to the $3.5 million of water sales revenue for the year ended December 31, 2019, primarily due to a decreased need for water use in drilling and completion operations due to the slowdown in industry activity as a result of the depressed commodity price environment in 2020.

Our Oil and Gas Producing Activities segment generated 100% and 94% of our total revenues for the years ended December 31, 2020 and 2019, respectively, with our Water Service Operations segment representing the remaining 0% and 6%, respectively.

Oil revenue for the year ended December 31, 2020 was $34.9 million as compared to $43.2 million for the year ended December 31, 2019, a decrease of $8.3 million. A decrease of $15.50/Bbl in our average price received for oil production, from $52.90/Bbl for the year ended December 31, 2019 to $37.40/Bbl for the year ended December 31, 2020, accounted for an approximate $14.5 million decrease in our year-over-year oil revenue, which was partially offset by an approximate $6.2 million increase in year-over-year oil revenue due to a 14% increase in oil production volumes, which increased from 816 Mbbls for the year ended December 31, 2019 to 933 Mbbls for the year ended December 31, 2020.

Natural gas revenue for the year ended December 31, 2020 was $4.3 million as compared to $2.4 million for the year ended December 31, 2019, an increase of $1.9 million. A 28% increase in gas production volumes, from 3,238 MMcf for the year ended December 31, 2019 to 4,134 MMcf for the year ended December 31, 2020, accounted for an approximate $0.7 million increase in year-over-year gas revenue and an increase of $0.29/Mcf in our average price received for gas production, from $0.74/Mcf for the year ended December 31, 2019 to $1.03 for the year ended December 31, 2020, accounted for an approximate $1.2 million increase in our year-over-year gas revenue.

NGLs revenue for the year ended December 31, 2020 was $5.0 million as compared to $5.3 million for the year ended December 31, 2019, a decrease of $0.3 million. A decrease of $3.16/Bbl in our average price received for NGLs production, from $13.48/Bbl for the year ended December 31, 2019 to $10.32/Bbl for the year ended December 31, 2020, accounted for an approximate $1.5 million decrease in our year-over-year NGLs revenue, which was partially offset by an approximate $1.2 million increase in year-over-year NGLs revenue due to a 24% increase in NGLs production volumes, which increased from 393 Mbbls for the year ended December 31, 2019 to 488 Mbbls for the year ended December 31, 2020.

Lease bonus revenue for the year ended December 31, 2020 was $0.7 million as compared to $2.8 million for the year ended December 31, 2019. When we lease our acreage to an E&P operator, we generally receive a lease bonus payment at the time a lease is executed. These bonus payments are subject to significant variability from period to period based on the particular tracts of land that become available for releasing. Other revenues for the year ended December 31, 2020 was $0.8 million as compared to $2.5 million for the year ended December 31, 2019 which include payments for right-of-way and surface damages, which are also subject to significant variability.

Operating Expenses

Management fees to affiliates expense remained consistent at $7.5 million for the years ended December 31, 2020 and 2019.


Depreciation, depletion and amortization expense was $32.0 million for the year ended December 31, 2020 as compared to $26.2 million for the year ended December 31, 2019, an increase of $5.8 million, or 22%. The increase was primarily due to a 21% increase in year-over-year production with the remaining 1% increase due to a higher depletion rate, which increased from $14.68/Boe for the year ended December 31, 2019 to $14.90/Boe for the year ended December 31, 2020 due to reserves decreasing at a higher rate than our net depletable capitalized costs from December 31, 2019 to December 31, 2020.

General and administrative expense was $5.0 million for the year ended December 31, 2020 as compared to $2.3 million for the year ended December 31, 2019, an increase of $2.7 million, or 112%. The increase was primarily due to increased personnel costs captured here for the first half of 2020 as noted below and professional services costs.

General and administrative—affiliates expense was $4.4 million for the year ended December 31, 2020 as compared to $8.2 million for the year ended December 31, 2019, a decrease of $3.8 million, or 46%. The decrease was primarily as a result of decreased reimbursement to our general partner for services provided on our behalf, including personnel costs. These costs were captured in the general and administrative expense line item for the first half of 2020. On a combined basis, the general and administrative expense and general and administrative expense—affiliates expense was $9.4 million for the year ended December 31, 2020 as compared to $10.5 million for the year ended December 31, 2019, a decrease of $1.1 million, or 11%, primarily due to decreased employee compensation and other cost-saving measures enacted in 2020 in connection with the depressed commodity price environment.

Impairment of oil and gas properties of approximately $0.8 million during the year ended December 31, 2020 was recognized in connection with capitalized acquisition costs for a prospective mineral interest acquisition that we did not complete.

Production costs, ad valorem taxes and operating expense was $3.2 million for the year ended December 31, 2020 as compared to $5.2 million for the year ended December 31, 2019, a decrease of $2.0 million or 40%. The decrease was primarily due to decreased operating expense for the water service operations segment, which was primarily due to a decreased need for water use in drilling and completion operations due to the slowdown in industry activity as a result of the depressed commodity price environment in 2020.

During the year ended December 31, 2020, we recognized approximately $2.7 million of expense in connection with the temporary postponement of an initial public offering. No such charges were incurred during the year ended December 31, 2019.

During the year ended December 31, 2020, we reversed approximately ($0.3) million of bad debt expense due to the collection of accounts receivable of KMF Water for which an allowance had previously been established. During the year ended December 31, 2019, we recognized approximately $0.4 million of bad debt expense associated with accounts receivable for KMF Water which we no longer believed were collectible.

Interest expense of approximately $2.0 million and $0.9 million during the years ended December 31, 2020 and 2019, respectively, relates to interest incurred on borrowings under our original credit facility. The increase in interest expense is primarily due to borrowings outstanding under our original credit facility for all of 2020, whereas we had no outstanding borrowings in 2019 until our entry into the original credit facility on September 26, 2019.

Income tax expense primarily relates to state franchise taxes, and totaled approximately $38,000 and $0.2 million for the years ended December 31, 2020 and 2019, respectively.


Segment Results

The following table sets forth certain financial information with respect to our reportable segments (in thousands):

 

     For the year ended December 31, 2020  
     Oil and
Gas
Producing
Activities
     Water
Service
Operations
     Partnership      Consolidated
Total
 

Revenues

   $ 43,113      $ 13      $ —        $ 43,126  

Depreciation, depletion and amortization

     31,746        303        —          32,049  

Income tax expense

     (38      —          —          (38

Interest expense

     (2,021      —          —          (2,021

Segment loss

     (6,253      (165      (7,849      (14,267

Total assets as of December 31, 2020

     591,140        3,602        3,886        598,628  

Capital expenditures, including mineral acquisitions

     35,836        —          —          35,836  

A reconciliation of segment profit (loss) to net income is as follows:

 

Segment loss

   $ (14,267

Interest income

     53  

Net loss

     (14,214

 

     For the year ended December 31, 2019  
     Oil and
Gas
Producing
Activities
     Water
Service
Operations
     Partnership      Consolidated
Total
 

Revenues

   $ 56,205      $ 3,475      $ —        $ 59,680  

Depreciation, depletion and amortization

     25,730        471        —          26,201  

Income tax (expense) benefit

     (166      3        (8      (171

Interest expense

     (1,099      (10      —          (1,109

Segment profit (loss)

     19,559        537        (11,547      8,549  

Total assets as of December 31, 2019

     608,170        5,445        18,190        631,805  

Capital expenditures, including mineral acquisitions

     266,942        637        —          267,579  

A reconciliation of segment profit (loss) to net income is as follows:

 

Segment profit

   $ 8,549  

Interest income

     241  

Net loss

     8,790  

Oil and Gas Producing Activities

Oil revenue for the year ended December 31, 2020 was $34.9 million as compared to $43.2 million for the year ended December 31, 2019, a decrease of $8.3 million. A decrease of $15.50/Bbl in our average price received for oil production, from $52.90/Bbl for the year ended December 31, 2019 to $37.40/Bbl for the year ended December 31, 2020, accounted for an approximate $14.5 million decrease in our year-over-year oil revenue, which was partially offset by an approximate $6.2 million increase in year-over-year oil revenue due to a 14% increase in oil production volumes, which increased from 816 Mbbls for the year ended December 31, 2019 to 933 Mbbls for the year ended December 31, 2020.

Natural gas revenue for the year ended December 31, 2020 was $4.3 million as compared to $2.4 million for the year ended December 31, 2019, an increase of $1.9 million. A 28% increase in gas production volumes, from 3,238 Mmcf for the year ended December 31, 2019 to 4,134 Mcf for the year ended December 31, 2020, accounted for an approximate $0.7 million increase in year-over-year gas revenue and an increase of $0.29/Mcf in our average price received for gas production, from $0.74/Mcf for the year ended December 31, 2019 to $1.03 for the year ended December 31, 2020, accounted for an approximate $1.2 million increase in our year-over-year gas revenue.


NGLs revenue for the year ended December 31, 2020 was $5.0 million as compared to $5.3 million for the year ended December 31, 2019, a decrease of $0.3 million. A decrease of $3.16/Bbl in our average price received for NGLs production, from $13.48/Bbl for the year ended December 31, 2019 to $10.32/Bbl for the year ended December 31, 2020, accounted for an approximate $1.5 million decrease in our year-over-year NGLs revenue, which was partially offset by an approximate $1.2 million increase in year-over-year NGLs revenue due to a 24% increase in NGLs production volumes, which increased from 393 Mbbls for the year ended December 31, 2019 to 488 Mbbls for the year ended December 31, 2020.

The following table presents the breakdown of our royalty revenues attributable to sales of crude oil, natural gas and NGLs totaling approximately $44.2 million and $50.9 million for the years ended December 31, 2020 and 2019, respectively:

 

     Year ended
December 31,
 
     2020     2019  

Royalty Revenue

    

Crude oil sales

     79     85

Natural gas sales

     10     5

NGLs sales

     11     10
  

 

 

   

 

 

 

Total Royalty Revenue

     100     100
  

 

 

   

 

 

 

Our oil and gas producing activities segment revenues are primarily a function of crude oil, natural gas, and NGLs production volumes sold and average prices received for those volumes, each of which can vary significantly from period to period. Despite such variability, we expect our royalty revenues to continue to be primarily attributable to crude oil sales.

Lease bonus and other income, which totaled approximately $1.5 million and $5.3 million for the years ended December 31, 2020 and 2019, respectively, is subject to significant variability from period to period based on the particular tracts of land that become available for releasing. Other revenues include payments for right-of-way and surface damages, which are also subject to significant variability.

Commodity derivatives losses totaled $2.6 million for the year ended December 31, 2020, whereas there were no derivatives gains or losses for the year ended December 31, 2019. In 2020, we entered into oil fixed price swaps and oil basis swaps to manage commodity price risks associated with our production. In October 2020, we terminated all of our outstanding oil and basis swap derivative contracts. We were not party to any derivative contracts as of December 31, 2020.

Operating expenses for the oil and gas producing activities segment totaled approximately $47.3 million for the year ended December 31, 2020, and consisted primarily of depreciation, depletion and amortization of $31.7 million, employee compensation and benefits of $6.1 million, general and administrative of $2.8 million, write off of deferred offering costs of $2.7 million, impairment of unproved oil and gas properties of $0.8 million, and production and ad valorem taxes of $3.2 million.

Operating expenses for the oil and gas producing activities segment totaled approximately $35.4 million for the year ended December 31, 2019, and consisted primarily of depreciation, depletion and amortization of $25.7 million, production and ad valorem taxes of $3.8 million, employee compensation and benefits of $5.7 million, and general and administrative of $0.1 million.

Income tax expense attributable to the oil and gas producing activities segment primarily relate to state franchise taxes, and totaled approximately $38,000 and $0.2 million for the years ended December 31, 2020 and 2019, respectively.

Water Service Operations

For the year ended December 31, 2020, there were no water sales. In April 2020, we entered into an agreement with a third-party water services company to manage our water assets and operations. The agreement constitutes a leasing arrangement under which we are a lessor. Under the terms of the agreement, we are not entitled to any income until the lessee has completed a water sale and received payment from its customer. Contingent rental income earned under this arrangement was $13,000 for the year ended December 31, 2020. For the year ended December 31, 2019, we sold approximately 6.2 million Bbls of water, generating revenue totaling approximately $3.5 million, or $0.56/Bbl. The decrease in overall income from the Water Service Operations segment was primarily due to a decreased need for water use in drilling and completion operations due to the slowdown in industry activity as a result of the depressed commodity price environment in 2020.


Operating expenses totaled approximately $0.2 million and $2.9 million for the years ended December 31, 2020 and 2019, respectively, and consisted primarily of gathering and hauling costs, electricity and fuel, depreciation, depletion and amortization and employee compensation.

Liquidity and Capital Resources

Overview

Prior to the completion of the Merger Transactions, our primary sources of liquidity have been contributions of capital from our limited partners, cash flows from operations and borrowings under our revolving credit facility. Subsequent to the completion of the Merger Transactions, cash flows from operations and borrowings under our revolving credit facility will be the primary day to day sources of our funds. Future sources of liquidity may also include other credit facilities we may enter into in the future and additional issuances of debt or equity securities. Our primary uses of cash have been, and are expected to continue to be, the acquisition of mineral and royalty interests. We also expect to pay dividends to our stockholders. Our ability to generate cash is subject to several factors, some of which are beyond our control, including commodity prices and general economic, financial, legislative, regulatory and other factors.

We believe internally generated cash flows from operations, available borrowing capacity under our revolving credit facility, and access to capital markets will provide us with sufficient liquidity and financial flexibility to continue to acquire attractive mineral and royalty interests that will position us to grow our cash flows and return capital to our stockholders. As an owner of mineral and royalty interests, we incur the initial cost to acquire our interests but thereafter do not incur any development or maintenance capital expenditures, which are entirely borne by the E&P operator and the other working interest owners. As a result, our only capital expenditures are related to our acquisition of additional mineral and royalty interests, and we have no other capital expenditure requirements. The amount and allocation of future acquisition-related capital expenditures will depend upon a number of factors, including the number and size of acquisition opportunities, our cash flows from operating, investing and financing activities and our ability to integrate acquisitions. We periodically assess changes in current and projected cash flows, acquisition and divestiture activities, and other factors to determine the effects on our liquidity. Our ability to generate cash is subject to a number of factors, many of which are beyond our control, including commodity prices, weather, general economic, financial and competitive, legislative, regulatory and other factors. If we require additional capital for acquisitions or other reasons, we may raise such capital through additional borrowings, asset sales, offerings of equity and debt securities or other means. If we are unable to obtain funds needed or on acceptable terms, we may not be able to complete acquisitions that are favorable to us.

As of March 31, 2022, our liquidity was $99.1 million, comprised of $13.6 million of cash and cash equivalents, $56.0 million of revolving credit facility availability and $29.5 million of unused capital commitments.

Cash Flows three months ended March 31, 2022 Compared to the three months ended March 31, 2021 (in thousands):

 

     For the Three Months Ended
March, 31,
 
     2022      2021  

Statement of Cash Flows Data:

     

Net cash provided by (used in):

     

Operating activities

   $ 44,603      $ 9,494  

Investing activities

     (3,376      51  

Financing activities

     (40,021      (8,526
  

 

 

    

 

 

 

Net increase in cash

   $ 1,206      $ 1,019  
  

 

 

    

 

 

 


Operating Activities

Our operating cash flows are impacted by the variability in our revenues and operating expenses, as well as the timing of the related cash receipts and disbursements. Royalty payments may vary significantly from period to period as a result of changes in commodity prices, production mix and volumes of production sold by our E&P operators and timeliness and accuracy of payments from our E&P operators. These factors are beyond our control and are difficult to predict. Cash flows provided by operating activities for the three months ended March 31, 2022 were $44.6 million as compared to $9.5 million for the three months ended March 31, 2021, primarily as a result of increases in realized prices and production volume from our oil and gas producing activities segment.

Investing Activities

Cash flows used in investing activities totaled $3.4 million for the three months ended March 31, 2022 as compared to cash flows provided by investing activities of $51,000 for the three months ended March 31, 2021, an increase of $3.4 million. During the three months ended March 31, 2022, we made advance deposits of $2.7 million for acquisitions of crude oil and gas properties. Such deposits are reclassified to oil and gas properties upon closure of the acquisitions. Our expenditures for purchases of oil and gas properties increased by $0.7 million related to certain capitalizable transaction costs.

Financing Activities

Cash flows used in financing activities for the three months ended March 31, 2022 totaled $40.0 million as compared to $8.5 million for the three months ended March 31, 2021, an increase of $31.5 million. Repayments on our credit facility for the three months ended March 31, 2022 and 2021 were $40.0 million and $8.5 million, respectively, largely provided by cash flows from operations.

Cash Flows Year Ended December 31, 2021 Compared to the Year Ended December 31, 2020 (in thousands):

 

     For the year ended
December 31,
 
     2021      2020  

Statement of Cash Flows Data:

     

Net cash provided by (used in):

     

Operating activities

   $ 65,929      $ 26,016  

Investing activities

     (38,743      (21,557

Financing activities

     (22,338      (15,061
  

 

 

    

 

 

 

Net increase (decrease) in cash

   $ 4,848      $ (10,602
  

 

 

    

 

 

 

Operating Activities

Our operating cash flows are impacted by the variability in our revenues and operating expenses, as well as the timing of the related cash receipts and disbursements. Royalty payments may vary significantly from period to period as a result of changes in commodity prices, production mix and volumes of production sold by our E&P operators and timeliness and accuracy of payments from our E&P operators. These factors are beyond our control and are difficult to predict. Cash flows provided by operating activities for the year ended December 31, 2021 were $65.9 million as compared to $26.0 million for the year ended December 31, 2020, primarily as a result of increases in realized prices and production volume from our oil and gas producing activities segment.

Investing Activities

Cash flows used in investing activities totaled $38.7 million for the year ended December 31, 2021 as compared to $21.6 million for the year ended December 31, 2020, an increase of $17.1 million. Our expenditures for crude oil and gas properties increased by $2.9 million in the year ended December 31, 2021 as compared to the year ended December 31, 2020. We paid $0.1 million related to purchase price adjustments from prior property sales for the year ended December 31, 2021, whereas we received proceeds from the sale of mineral interests of $14.1 million for the year ended December 31, 2020. Although we completed several acquisitions during the year ended December 31, 2021, the three largest acquisitions were completed through the issuance of equity in one of our consolidated subsidiaries with no cash consideration provided. The properties acquired through these acquisitions increased the balance of our oil and gas properties by $572.2 million. See our audited consolidated financial statements for the year ended December 31, 2021 and 2020 included as Exhibit 99.3 to the Form 8-K for additional information.


Financing Activities

Cash flows used in financing activities for the year ended December 31, 2021 totaled $22.3 million as compared to $15.1 million for the year ended December 31, 2020, an increase of $7.2 million. Capital contributions from our partners totaled $8.0 million and $13.0 million during the years ended December 31, 2021 and 2020, respectively, which were primarily used for the acquisition of mineral and royalty interests. Borrowings on our credit facility for the years ended December 31, 2021 and 2020 totaled $147.0 million and $10.0 million, respectively, which were also used for the acquisition of mineral and royalty interests and distributions to members of DPM HoldCo. Repayments on our credit facility for the years ended December 31, 2021 and 2020 were $46.5 million and $36.5 million, respectively, largely provided by cash flows from operations as well as the sale of certain properties to another mineral owner during the year ended December 31, 2020.

Cash Flows Year Ended December 31, 2020 Compared to the Year Ended December 31, 2019 (in thousands):

 

     For the Year Ended
December 31,
 
     2020      2019  

Statement of Cash Flows Data:

     

Net cash provided by (used in):

     

Operating activities

   $ 26,016      $ 34,791  

Investing activities

     (21,557      (248,627

Financing activities

     (15,061      221,954  
  

 

 

    

 

 

 

Net (decrease) increase in cash

   $ (10,602    $ 8,118  
  

 

 

    

 

 

 

Operating Activities

Our operating cash flows are impacted by the variability in our revenues and operating expenses, as well as the timing of the related cash receipts and disbursements. Royalty payments may vary significantly from period to period as a result of changes in commodity prices, production mix and volumes of production sold by our E&P operators and timeliness and accuracy of payments from our E&P operators. Additionally, revenues and operating expenses within our Water Service Operations segment are subject to significant variability due to fluctuations in market pricing, demand and competition. These factors are beyond our control and are difficult to predict. Cash flows provided by operating activities for the year ended December 31, 2020 were $26.0 million as compared to $34.8 million for the year ended December 31, 2019, primarily as a result of decreases in realized prices from our oil and gas producing activities segment as well as $2.6 million of commodity derivative losses incurred for the year ended December 31, 2020.

Investing Activities

Cash flows used in investing activities totaled $21.6 million for the year ended December 31, 2020 as compared to $248.6 million for the year ended December 31, 2019, a decrease of $227.0 million. Our expenditures for crude oil and gas properties and proceeds from sale of oil and gas properties decreased by $231.0 million and $8.0 million respectively in 2020 as compared to 2019. Although we continued to evaluate and pursue acquisitions of attractive mineral and royalty interests during 2020, we were unable to reach agreeable terms, which resulted in a significant decline in our acquisition activity. During the year ended December 31, 2019, we placed $3.1 million in an escrow account for an acquisition of crude oil and gas properties, which was reclassified to oil and gas properties during the year ended December 31, 2020.

Financing Activities

Cash flows used in financing activities for the year ended December 31, 2020 totaled $15.1 million as compared to cash flows provided by financing activities for the year ended December 31, 2019 of $222.0 million. Capital contributions from our partners totaled $13.0 million and $164.7 million for the years ended December 31, 2020 and 2019, respectively, which were primarily used for the acquisition of mineral and royalty interests. Borrowings on our credit facility for the years ended December 31, 2020 and 2019 totaled $10.0 million and $60.0 million,


respectively, which were also used for the acquisition of mineral and royalty interests. Credit facility borrowings during the year ended December 31, 2020 were offset by repayments of $36.5 million, largely provided by cash flows from operations as well as the sale of certain properties to another mineral owner. There were no repayments on our credit facility during the year ended December 31, 2019.

Our Revolving Credit Facility

On October 8, 2021, KMF Land, as borrower, Desert Peak, as parent, Bank of America, N.A., as the administrative agent and issuing bank, and certain lenders entered into the Existing Credit Agreement, pursuant to which the lenders thereunder made loans and other extensions of credit to the borrower thereunder.

On the Closing Date, the Existing Credit Agreement was amended and restated in its entirety pursuant to the Credit Agreement. The Credit Agreement has a scheduled maturity date in June 2026. Pursuant to the terms and conditions of the Credit Agreement, the Lenders committed to providing a credit facility to Sitio OpCo in an aggregate principal amount of up to $750 million. The availability under the Credit Agreement, including availability for letters of credit, is generally limited to a borrowing base, which is determined by the required number of lenders in good faith by calculating a loan value of the proved reserves of Sitio OpCo and its subsidiaries and elected commitments provided by the Lenders. As of the Closing Date, the Credit Agreement has a $300 million borrowing base and $300 million elected commitment amount. As part of the aggregate commitments under the revolving advances, the Credit Agreement provides for letters of credit to be issued at the request of the borrower in an aggregate amount not to exceed $15 million. Existing letters of credit in place under the Existing Credit Agreement immediately prior to the Closing Date are continued and now deemed issued under and governed by the terms of the Credit Agreement.

Interest accrues on advances, at the borrower’s option, at a Term SOFR rate or a base rate, plus an applicable margin. The fees for letters of credit are also based on the applicable margin. The applicable margin used in connection with interest rates and fees is based on the Borrowing Base Utilization Percentage (as defined in the Credit Agreement). The applicable margin for Term SOFR rate loans and letter of credit fees ranges from 2.500% to 3.500%, and the applicable margin for base rate loans ranges from 1.500% to 2.500%. The borrower will also pay a fee based on the borrowing base utilization percentage on the actual daily unused amount of the aggregate revolving commitments ranging from 0.375% to 0.500%.

The borrowings under the Credit Agreement are secured by liens on certain assets of the borrower, the borrower’s subsidiaries and Sitio Royalties GP, LLC, a Delaware limited liability company, and guaranteed by the borrower and the borrower’s subsidiaries. Proceeds from borrowings under the Credit Agreement may be used (i) for working capital, exploration and production operations, and other general company purposes including acquisitions, (ii) for payment of certain transaction fees and expenses, and (iii) to repay third party debt of the borrower and its subsidiaries existing prior to the Closing Date.

The Credit Agreement contains customary representations, warranties, covenants and events of default, including, among others, a change of control event of default and limitations on the incurrence of indebtedness and liens, new lines of business, mergers, transactions with affiliates and burdensome agreements. During the continuance of an event of default, the Lenders may take a number of actions, including, among others, declaring the entire amount then outstanding under the Credit Agreement to be due and payable.

The Credit Agreement includes a financial covenant limiting, as of the last day of each fiscal quarter, the ratio of (a) (i) Total Net Debt (as defined in the Credit Agreement) as of such date to (ii) EBITDA (as defined in the Credit Agreement) for the period of four fiscal quarters ending on such day (the “Leverage Ratio”), to not more than 3.50 to 1.00, and (b) (i) consolidated current assets (including the available commitments under the Credit Agreement) to (ii) consolidated current liabilities (excluding current maturities under the Credit Agreement), to not less than 1.00 to 1.00, in each case, with certain rights to cure.

Internal Controls and Procedures

We are not currently required to comply with the SEC’s rules related to the implementation of Section 404 of the Sarbanes-Oxley Act, and are therefore not required to make a formal assessment of the effectiveness of our internal control over financial reporting for that purpose. Upon becoming a public company, we will be required to


comply with the SEC’s rules implementing Section 302 of the Sarbanes-Oxley Act, which will require our management to certify financial and other information in our quarterly and annual reports and provide an annual management report on the effectiveness of our internal control over financial reporting. To comply with the requirements of being a public company, we will need to implement additional financial and management controls, systems, processes and procedures.

Further, our independent registered public accounting firm is not yet required to formally attest to the effectiveness of our internal controls over financial reporting.

New and Revised Financial Accounting Standards

Refer to “Recent Accounting Pronouncements” in Note 2, “Basis of Presentation and Summary of Significant Accounting Policies” to our audited consolidated financial statements for the years ended December 31, 2021, 2020 and 2019 included as Exhibit 99.3 to the Form 8-K and Note 2, “Basis of Presentation and Summary of Significant Accounting Policies” to our unaudited condensed consolidated financial statements for the three months ended March 31, 2022 and 2021 included as Exhibit 99.4 to the Form 8-K for a discussion of recent accounting pronouncements.

Critical Accounting Policies and Related Estimates

The discussion and analysis of financial condition and results of operations are based upon our consolidated financial statements, which have been prepared in accordance with GAAP. Our critical accounting policies are described below to provide a better understanding of how we develop our assumptions and judgments about future events and related estimates and how they can impact our financial statements. A critical accounting estimate is one that requires our most difficult, subjective or complex estimates and assessments and is fundamental to our results of operations.

We base our estimates on historical experience and on various other assumptions we believe to be reasonable according to the facts and circumstances at the time the estimates are made. Uncertainties with respect to such estimates and assumptions are inherent in the preparation of financial statements. There can be no assurance that actual results will not differ from those estimates and assumptions. This discussion and analysis should be read in conjunction with our consolidated financial statements and related notes included as exhibits to the Form 8-K.

Use of Estimates

The preparation of financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates. Changes in estimates are accounted for prospectively.

Our estimates and classification of oil and natural gas reserves are, by necessity, projections based on geologic and engineering data, and there are uncertainties inherent in the interpretation of such data as well as the projection of future rates of production. Reserve engineering is a subjective process of estimating underground accumulations of oil and natural gas that are difficult to measure. The accuracy of any reserve estimate is a function of the quality of available data, engineering, and geological interpretation and judgment. Estimates of economically recoverable oil and natural gas reserves and future net cash flows necessarily depend upon a number of variable factors and assumptions. These factors and assumptions include historical production from the area compared with production from other producing areas, the assumed effect of regulations by governmental agencies, and assumptions governing future oil and natural gas prices. For these reasons, estimates of the economically recoverable quantities of expected oil and natural gas and estimates of the future net cash flows may vary substantially.

Any significant variance in the assumptions could materially affect the estimated quantity of reserves, which could affect the carrying value of our oil and natural gas properties and/or the rate of depletion related to oil and natural gas properties.


Oil and Gas Properties

We use the successful efforts method of accounting for oil and natural gas producing properties, as further defined under ASC 932, Extractive Activities—Oil and Natural Gas. Under this method, costs to acquire mineral interests in oil and natural gas properties are capitalized. The costs of non-producing mineral interests and associated acquisition costs are capitalized as unproved properties pending the results of leasing efforts and drilling activities of E&P operators on our interests. As unproved properties are determined to have proved reserves, the related costs are transferred to proved oil and gas properties. Capitalized costs for proved oil and natural gas mineral interests are depleted on a unit-of-production basis over total proved reserves. For depletion of proved oil and gas properties, interests are grouped in a reasonable aggregation of properties with common geological structural features or stratigraphic conditions.

Impairment of Oil and Gas Properties

We evaluate our proved properties for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. When assessing proved properties for impairment, we compare the expected undiscounted future cash flows of the proved properties to the carrying amount of the proved properties to determine recoverability. If the carrying amount of proved properties exceeds the expected undiscounted future cash flows, the carrying amount is written down to the properties’ estimated fair value, which is measured as the present value of the expected future cash flows of such properties. The factors used to determine fair value include estimates of proved reserves, future commodity prices, timing of future production, and a risk-adjusted discount rate. The proved property impairment test is primarily impacted by future commodity prices, changes in estimated reserve quantities, estimates of future production, overall proved property balances, and depletion expense. If pricing conditions decline or are depressed, or if there is a negative impact on one or more of the other components of the calculation, we may incur proved property impairments in future periods.

Unproved oil and gas properties are assessed periodically for impairment of value, and a loss is recognized at the time of impairment by charging capitalized costs to expense. Impairment is assessed based on when facts and circumstances indicate that the carrying value may not be recoverable, at which point an impairment loss is recognized to the extent the carrying value exceeds the estimated recoverable value. Factors used in the assessment include but are not limited to commodity price outlooks, current and future operator activity in the Permian Basin, and analysis of recent mineral transactions in the surrounding area.

Crude Oil, Natural Gas and NGLs Reserve Quantities and Standardized Measure of Oil and Gas

Our estimates of crude oil, natural gas and NGLs reserves and associated future net cash flows are prepared by our independent reservoir engineers. The SEC has defined proved reserves as the estimated quantities of oil and gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. The process of estimating crude oil, natural gas and NGLs reserves is complex, requiring significant decisions in the evaluation of available geological, geophysical, engineering and economic data. The data for a given property may also change substantially over time as a result of numerous factors, including additional development activity, evolving production history and a continual reassessment of the viability of production under changing economic conditions. As a result, material revisions to existing reserve estimates occur from time to time. Although every reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the decisions and variances in available data for various properties increase the likelihood of significant changes in these estimates. If such changes are material, they could significantly affect future amortization of capitalized costs and result in impairment of assets that may be material.

There are numerous uncertainties inherent in estimating quantities of proved crude oil, natural gas and NGLs reserves. Crude oil, natural gas and NGLs reserve engineering is a process of estimating underground accumulations of crude oil, natural gas and NGLs that cannot be precisely measured and the accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing and production subsequent to the date of the estimate may justify positive or negative revisions of reserve estimates.


Revenue Recognition

Mineral and royalty interests represent the right to receive revenues from the sale of oil, natural gas and NGLs, less production taxes and post-production expenses. The prices of oil, natural gas, and NGLs from the properties in which we own a mineral or royalty interest are primarily determined by supply and demand in the marketplace and can fluctuate considerably. As an owner of mineral and royalty interests, we have no working interest or operational control over the volumes and methods of sale of the oil, natural gas, and NGL produced and sold from our properties. We do not explore, develop, or operate the properties and, accordingly, do not incur any of the associated costs.

Oil, natural gas, and NGLs revenues from our mineral and royalty interests are recognized when control transfers at the wellhead.

Water sales for the year ended December 31, 2019 were recognized when control of the water was transferred to an E&P operator and collectability was reasonably assured. In April 2020, we entered into an agreement with a third-party water services company to manage our water assets and operations. The agreement constituted a leasing arrangement under which we were a lessor. Under the terms of the agreement, we were not entitled to any income until the lessee had completed a water sale and received payment from its customer. The agreement was terminated in October 2021.

We also earn revenue related to lease bonuses by leasing our mineral interests to E&P companies. We recognize lease bonus revenue when the lease agreement has been executed and payment is determined to be collectible. We do not accrue this contingent rental income until the lessee has received payment.

Contractual Obligations

As of March 31, 2022, we did not have any long-term debt, capital lease obligations, operating lease obligations or long-term liabilities, other than borrowings under our revolving credit facility, two operating lease agreements for office space, and an obligation to pay Kimmeridge an annual fee under an investment management agreement. Please see “—Our Revolving Credit Facility” for a description of our revolving credit facility, and Note 11 to our interim unaudited condensed consolidated financial statements for the three months ended March 31, 2022 and 2021 included as Exhibit 99.4 to the Form 8-K for our contractual obligations under the office lease agreements. Fees incurred under the management services arrangement totaled approximately $1.9 million for the three months ended March 31, 2022 and 2021, respectively. We do not expect to incur future expense under the management services arrangement following the completion of the Merger Transactions.

Quantitative and Qualitative Disclosure about Market Risk

Commodity Price Risk

Our major market risk exposure is in the pricing applicable to the crude oil, natural gas and NGLs production of our E&P operators, which affects the royalty payments we receive from our E&P operators. Realized pricing is primarily driven by the prevailing worldwide price for crude oil and spot market prices applicable to our natural gas production. Pricing for crude oil, natural gas and NGLs production has been volatile historically and we expect this volatility to continue in the future. The prices that our E&P operators receive for production depend on many factors outside of our or their control.

A $1.00 per Bbl change in our realized oil price would have resulted in a $0.5 million change in our oil revenues for the three months ended March 31, 2022. A $0.10 per Mcf change in our realized natural gas price would have resulted in a $0.2 million change in our natural gas revenues for the three months ended March 31, 2022. A $1.00 per Bbl change in NGL prices would have resulted in a $0.2 million change in our NGL revenues for the three months ended March 31, 2022. Royalties on oil sales contributed 76% of our mineral and royalty revenues for the three months ended March 31, 2022. Royalties on natural gas sales contributed 12% and royalties on NGL sales contributed 12% of our total mineral and royalty revenues for the three months ended March 31, 2022.


A $1.00 per Bbl change in our realized oil price would have resulted in a $1.3 million change in our oil revenues for the year ended December 31, 2021. A $0.10 per Mcf change in our realized natural gas price would have resulted in a $0.5 million change in our natural gas revenues for the year ended December 31, 2021. A $1.00 per Bbl change in NGL prices would have resulted in a $0.5 million change in our NGL revenues for the year ended December 31, 2021. Royalties on oil sales contributed 72% of our mineral and royalty revenues for the year ended December 31, 2021. Royalties on natural gas sales contributed 14% and royalties on NGL sales contributed 14% of our total mineral and royalty revenues for the year ended December 31, 2021.

A $1.00 per Bbl change in our realized oil price would have resulted in a $0.9 million change in our oil revenues for the year ended December 31, 2020. A $0.10 per Mcf change in our realized natural gas price would have resulted in a $0.4 million change in our natural gas revenues for the year ended December 31, 2020. A $1.00 per Bbl change in NGL prices would have resulted in a $0.5 million change in our NGL revenues for the year ended December 31, 2020. Royalties on oil sales contributed 79% of our mineral and royalty revenues for the year ended December 31, 2020. Royalties on natural gas sales contributed 10% and royalties on NGL sales contributed 11% of our total mineral and royalty revenues for the year ended December 31, 2020.

Credit Risk

The collectability of our royalty revenue is dependent upon the financial condition of our E&P operators, as well as general economic conditions in the industry.

For the three months ended March 31, 2022, in the Oil and Gas Producing Activities segment, revenue from Callon Petroleum Company represented approximately 17% of total revenue. This figure is the same as total revenues due to the fact that revenues attributable to the Water Services Operations segment for the three months ended March 31, 2022 were de minimis.

For the year ended December 31, 2021, in the Oil and Gas Producing Activities segment, revenue from Coterra Energy Inc., Diamondback Energy, Inc, Callon Petroleum Company, and Oxy USA Inc represented approximately 12%, 11%, 11%, and 10% of total revenue, respectively. These figures are the same as total revenues due to the fact that revenues attributable to the Water Services Operations segment for the year ended December 31, 2021 were de minimis.

For the year ended December 31, 2020, in the Oil and Gas Producing Activities segment, revenue from Diamondback Energy, Inc, Cimarex Energy, and Oxy USA Inc represented approximately 15%, 12% and 10% of total revenue, respectively. These figures are the same as total revenues due to the fact that revenues attributable to the Water Services Operations segment for the year ended December 31, 2020 were de minimis.

For the year ended December 31, 2019, in the Oil and Gas Producing Activities segment, revenue from Cimarex Energy, Oxy USA Inc and PDC Energy represented approximately 16%, 10% and 10% of total revenue, respectively. In the Water Services Operations segment PDC Energy Inc., WPX Energy, Oxy USA Inc. and BTA Oil Producers represented 37%, 24%, 20% and 16% of total revenue, respectively. Combining both the Water Services Operations and Oil and Gas Producing Activities segments, Cimarex Energy, PDC Energy, and Oxy USA Inc represented approximately 15%, 12% and 11% of total revenue, respectively.

Although we are exposed to a concentration of credit risk, we do not believe the loss of any single purchaser would materially impact our operating results as crude oil and natural gas are fungible products with well-established markets and numerous purchasers. If multiple purchasers were to cease making purchases at or around the same time, we believe there would be challenges initially, but there would be ample markets to handle the disruption. Additionally, recent rulings in bankruptcy cases involving our E&P operators have stipulated that royalty owners must still be paid for oil, gas and NGLs extracted from their mineral acreage during the bankruptcy process. In light of this, we do not expect the entry of one of our operators into bankruptcy proceedings to materially affect our operating results.

Interest Rate Risk

Our primary exposure to interest rate risk results from outstanding borrowings under our revolving credit facility, which has a floating interest rate. The average annual interest rate incurred on our borrowings under the Existing Credit Agreement during the three months ended March 31, 2022 was 3.26%. We estimate that an increase of 1.0% in the average interest rate during the three months ended March 31, 2022 would have resulted in an


approximately $0.3 million increase in interest expense. The average annual interest rate incurred on our borrowings under the Existing Credit Agreement during the three months ended March 31, 2021 was 2.62%. We estimate that an increase of 1.0% in the average interest rate during the three months ended March 31, 2021 would have resulted in an approximately $0.1 million increase in interest expense.

Exhibit 99.6

UNAUDITED PRO FORMA CONDENSED CONSOLIDATED

COMBINED FINANCIAL STATEMENTS

Defined terms included below shall have the same meaning as terms defined and included elsewhere in the definitive proxy statement filed by Falcon with the Securities and Exchange Commission (“SEC”) on May 5, 2022 (the “Proxy Statement”).

On January 11, 2022, Sitio Royalties Corp., a Delaware corporation (formerly known as Falcon Minerals Corporation) (the “Company” or “Falcon”) entered into a Merger Agreement with Sitio Royalties Operating Partnership, LP, a Delaware limited partnership (formerly known as Falcon Minerals Operating Partnership, LP) (“Sitio OpCo”), Merger Sub, and Desert Peak, pursuant to which Merger Sub merged with and into Desert Peak, with Desert Peak continuing as the surviving entity in the Merger as a wholly owned subsidiary of Sitio OpCo. Pursuant to the Merger Agreement, at the effective time of the Merger, the limited liability company interests in Desert Peak issued and outstanding immediately prior to the Merger Effective Time were converted into the right to receive Merger Consideration consisting of an aggregate of 61,905,339 shares of the Company’s issued and outstanding Class C Common Stock, par value $0.0001 per shares (“Class C Common Stock”), and 61,905,339 common units representing limited partner interests in Sitio OpCo (the “Partnership Units”). The Merger Consideration was adjusted to give effect to the Falcon Reverse Stock Split. The Company’s warrants remain outstanding following such transactions. However, as a result of the Falcon Reverse Stock Split, the outstanding warrants were adjusted such that four warrants became exercisable for one share of the Company’s Class A Common Stock, par value $0.0001 per share (“Class A Common Stock” and, together with the Class C Common Stock, the “Common Stock”), at an exercise price of approximately $44.84 per share of Class A Common Stock. Further, following completion of the Merger, the warrants will continue to be treated as liability classified financial instruments under ASC 815-40 Derivatives and Hedging – Contracts in Entity’s Own Equity. The transactions contemplated by the Merger Agreement, including the Falcon Reverse Stock Split, are referred to herein as the “Merger Transactions” and the adjustments related thereto are referred to as the “Transaction Adjustments.”

The following unaudited pro forma condensed consolidated combined financial statements (the “pro forma financial statements”) present the historical consolidated financial statements of KMF, Desert Peak’s predecessor for financial reporting purposes, and the historical consolidated financial statements of Falcon, adjusted to give effect to the Merger Transactions. Additionally, the pro forma financial statements include adjustments associated with the Desert Peak Acquisitions (together with the Merger Transactions, the “Transactions”) completed by Desert Peak prior to the Merger (the “Desert Peak Adjustments”):

 

   

the acquisition on June 7, 2021 of approximately 7,200 NRAs from Chambers Minerals, LLC, an affiliate of Kimmeridge, consisting of a 2.0% (on an 8/8ths basis) overriding royalty interest, proportionately reduced to Callon Petroleum Company’s (“Callon”) net revenue interest, in substantially all Callon-operated oil and gas leaseholds in the Delaware Basin (the “Chambers Acquisition”);

 

   

the acquisition on June 30, 2021 of approximately 18,500 NRAs from Rock Ridge Royalty, LLC (the “Rock Ridge Acquisition”); and

 

   

the acquisition on August 31, 2021 of approximately 25,000 NRAs from Source Energy Leasehold, LP and Permian Mineral Acquisition, LP (the “Source Acquisition”).

The unaudited pro forma condensed consolidated combined balance sheet gives effect to the Transactions as if they had occurred on March 31, 2022. The Desert Peak Acquisitions are reflected in the historical consolidated balance sheet of KMF as of March 31, 2022, and, as such, no pro forma adjustments are made for such transactions in the unaudited pro forma condensed consolidated combined balance sheet. The unaudited pro forma condensed consolidated combined statements of operations for the three months ended March 31, 2022 and for the year ended December 31, 2021 give effect to the Transactions as if they had occurred January 1, 2021. The pro forma financial statements contain certain reclassification adjustments to (i) conform the historical KMF financial statement presentation to Falcon’s financial statement presentation and (ii) conform certain of Falcon’s historical amounts to KMF’s financial statement presentation.

 

1


The unaudited pro forma financial statements have been prepared in accordance with Article 11 of Regulation S-X as amended by the final rule, Release No. 33-10786, ”Amendments to Financial Disclosures about Acquired and Disposed Businesses,” using assumptions set forth in the notes to the unaudited pro forma financial statements. The pro forma financial statements have been adjusted to include transaction accounting adjustments in accordance with GAAP, linking the effects of the Transaction Adjustments and the Desert Peak Adjustments to the historical consolidated financial statements of KMF. As of the date of this Proxy Statement, the detailed valuation study necessary to arrive at the required final estimates of the fair value of the Falcon assets to be acquired and the liabilities to be assumed and the related allocations of purchase price has not been completed, nor have all necessary adjustments been made to conform Falcon’s accounting policies to Desert Peak’s accounting policies. A final determination of the fair value of Falcon’s assets and liabilities will be based on the actual assets and liabilities of Falcon that exist as of the Merger Effective Time and, therefore, cannot be made prior to the completion of the Merger.

The pro forma financial statements and related notes are presented for illustrative purposes only and should not be relied upon as an indication of the financial condition or the operating results that Desert Peak would have achieved if the Transactions had taken place on the assumed dates. The pro forma financial statements do not reflect future events that may occur after the consummation of the Merger, including, but not limited to, the anticipated realization of ongoing savings from potential operating efficiencies, asset dispositions, cost savings, or economies of scale that may be achieved with respect to the combined operations. As a result, future results may vary significantly from the results reflected in the pro forma financial statements and should not be relied on as an indication of the Post-Combination Company’s future results.

 

2


Pro Forma Condensed Consolidated Combined Balance Sheet

As of March 31, 2022

(Unaudited)

 

     Historical     Transaction
Adjustments
         Pro Forma
Combined
 
     Kimmeridge
Mineral Fund,
L.P. (Desert Peak
Predecessor)
    Falcon Minerals
Corporation
     
     (In thousands, except share amounts)  

ASSETS

         B       

Current assets:

           

Cash and cash equivalents

   $ 13,585     $ 2,921     $ (2,120   A    $ 14,386  

Accounts receivable

     48,488       11,844       (8   A      60,324  

Other current assets

     345       856       —            1,201  
  

 

 

   

 

 

   

 

 

      

 

 

 

Total current assets

     62,418       15,621       (2,128        75,911  
  

 

 

   

 

 

   

 

 

      

 

 

 

Property and equipment:

           

Oil and natural gas properties, successful efforts method:

           

Unproved properties

     795,736       27,274       402,260          1,225,270  

Proved properties

     470,002       325,948       (125,175        670,775  

Property and equipment

     8,424       606       (6,023   A      2,697  
         (310     

Accumulated depreciation, depletion, and amortization

     (136,921     (163,412     163,412          (134,140
         2,781     A   
  

 

 

   

 

 

   

 

 

      

 

 

 

Net oil and gas properties and other property and equipment

     1,137,241       190,416       436,945          1,764,602  
  

 

 

   

 

 

   

 

 

      

 

 

 

Other long-term assets:

           

Deposits for property acquisitions

     2,700              2,700  

Deferred tax assets

       51,655       (16,245        35,410  

Other assets

     2,226       1,344       —            3,570  
  

 

 

   

 

 

   

 

 

      

 

 

 

Total long-term assets

     4,926       52,999       (16,245        41,680  
  

 

 

   

 

 

   

 

 

      

 

 

 

TOTAL ASSETS

   $ 1,204,585     $ 259,036     $ 418,572        $ 1,882,193  
  

 

 

   

 

 

   

 

 

      

 

 

 

LIABILITIES AND EQUITY

           

Current liabilities:

           

Accounts payable and accrued expenses

   $ 6,538     $ 6,463     $ 25,000     C    $ 37,962  
         (39   A   

Other current liabilities

     —         199       —            199  

Due to affiliates

     121       —         —            121  

Derivative liabilities

     468       —         —            468  
  

 

 

   

 

 

   

 

 

      

 

 

 

Total current liabilities

     7,127       6,662       24,961          38,750  
  

 

 

   

 

 

   

 

 

      

 

 

 

Long-term liabilities:

           

Long-term debt

     94,000       38,000       —            132,000  

Warrant liability

     —         8,225       —            8,225  

Other non-current liabilities

     1,147       415       —            1,562  

Long-term derivative liabilities

     646              646  
  

 

 

   

 

 

   

 

 

      

 

 

 

Total liabilities

     102,920       53,302       24,961          181,183  

 

3


     Historical      Transaction
Adjustments
         Pro Forma
Combined
 
     Kimmeridge
Mineral
Fund, L.P.
(Desert Peak
Predecessor)
     Falcon
Minerals
Corporation
     
     (In thousands, except share amounts)  

COMMITMENTS AND CONTINGENCIES

             

Temporary equity

           553,096     E      1,521,724  
           521,763     F   
           82,697     E   
           364,168     G   

Permanent equity:

             

Class A common stock (47,106,218 and 11,937,956 shares issued and outstanding on a historical and pro forma basis, respectively)

        5        (4   G      1  

Class C common stock (39,387,782 and 71,752,286 shares issued and outstanding on a historical and pro forma basis, respectively)

        4        3     G      7  

Additional paid-in capital

        121,349        (6,546   E      179,278  
           59,775     G   
           4,700     D   

Retained earnings

        1,679        (3,525   C      —    
           (4,700   D   
           6,546     E   

Partners’ capital

     579,902           (553,096   E      —    
           (5,331   A   
           (21,475   C   

Non-controlling interest

     521,763        82,697        (82,697   E      —    
           (521,763   F   
  

 

 

    

 

 

    

 

 

      

 

 

 

Permanent equity

     1,101,665        205,734        (1,128,113        179,286  
  

 

 

    

 

 

    

 

 

      

 

 

 

Total liabilities, temporary equity and permanent equity

   $ 1,204,585      $ 259,036      $ 418,572        $ 1,882,193  
  

 

 

    

 

 

    

 

 

      

 

 

 

 

4


Pro Forma Condensed Consolidated Combined Statement of Operations

For the Three Months Ended March 31, 2022

(Unaudited)

 

     Historical                As Adjusted          Historical                       
     Kimmeridge
Mineral
Fund L.P.
(DPM
Predecessor)
    DPM
Predecessor
Transaction
Adjustments
         Kimmeridge
Mineral
Fund L.P.
(DPM
Predecessor)
         Falcon
Minerals
Corporation
    Transaction
Adjustments
         Pro Forma
Combined
     

Revenue:

                       

Oil, natural gas and natural gas liquids revenues

   $ 64,951     $          $ 64,951        $ 21,828     $          $ 86,779    

Lease bonus and other income

     1,412            1,412          779       (102   D      2,089    

Commodity derivatives losses

            —            (302     302     J      —      
  

 

 

   

 

 

      

 

 

      

 

 

   

 

 

      

 

 

   

Total revenue

     66,363       —            66,363          22,305       200          88,868    
  

 

 

   

 

 

      

 

 

      

 

 

   

 

 

      

 

 

   

Operating Expenses:

                       

Management fees to affiliates

     1,870            1,870     I             1,870    

Depreciation, depletion and amortization

     15,385       (734   H      14,651          3,424       503     H      18,506    
                   (72   D     

General and administrative

     3,983            3,983          5,865       (67   D      34,781    
                   25,000     F     

General and administrative—affiliates

     80            80                 80    

Severance and ad valorem taxes

     3,725            3,725          1,365            5,090    

Marketing and transportation

                 374            374    
  

 

 

   

 

 

      

 

 

      

 

 

   

 

 

      

 

 

   

Total operating expenses

     25,043       (734        24,309          11,028       25,364          60,701    
  

 

 

   

 

 

      

 

 

      

 

 

   

 

 

      

 

 

   

Net income (loss) from operations

     41,320       734          42,054          11,277       (25,164        28,167    

Other income (expense):

                       

Other income (expense)

            —            (5,176          (5,176  

Interest income (expense), net

     (1,168          (1,168        (493          (1,661  

Commodity derivative losses

     (1,114          (1,114          (302   J      (1,416  
  

 

 

   

 

 

      

 

 

      

 

 

   

 

 

      

 

 

   

Total other income (expense)

     (2,282     —            (2,282        (5,669     (302        (8,253  
  

 

 

   

 

 

      

 

 

      

 

 

   

 

 

      

 

 

   

Net income before income tax expense

     39,038       734          39,772          5,608       (25,466        19,914    
    

 

 

                    

Income tax (expense) benefit

     (516          (516        (1,820     (2,046   K      (4,382  
  

 

 

   

 

 

      

 

 

      

 

 

   

 

 

      

 

 

   

Net income

   $ 38,522     $ 734        $ 39,256        $ 3,788     $ (27,512      $ 15,532    
  

 

 

   

 

 

      

 

 

      

 

 

   

 

 

      

 

 

   

Less net income attributable to temporary equity

                   13,345     L      13,345    

Less net income attributable to non-controlling interests

     19,242            19,242          4,917       (24,159   L      —      
  

 

 

   

 

 

      

 

 

      

 

 

   

 

 

      

 

 

   

Net income (loss) attributable to Desert Peak Minerals Inc.

   $ 19,280     $ 734        $ 20,014        $ (1,129   $ (16,698      $ 2,187    
  

 

 

   

 

 

      

 

 

      

 

 

   

 

 

      

 

 

   

Net Income (Loss) per Common Share

                       

Basic

                 (0.03          0.17     M

Diluted

                 (0.03          0.17     M

 

5


     Historical                 As Adjusted          Historical                        
     Kimmeridge
Mineral
Fund L.P.
(DPM
Predecessor)
     DPM
Predecessor
Transaction
Adjustments
         Kimmeridge
Mineral
Fund L.P.
(DPM
Predecessor)
         Falcon
Minerals
Corporation
     Transaction
Adjustments
         Pro Forma
Combined
     

Weighted Average Common Shares Outstanding

                         

Basic

                  47,048             11,762     M

Diluted

                  47,048             11,762     M

 

6


Pro Forma Condensed Consolidated Combined Statement of Operations

For the Year Ended December 31, 2021

(Unaudited)

 

    Historical     Desert Peak Adjustments     DPM
Predecessor
Transaction
Adjustments
        As Adjusted         Historical     Transaction
Adjustments
        Pro- Forma
Combined
     
    Kimmeridge
Mineral
Fund L.P.
(DPM
Predecessor)
    Chambers
Acquisition
    Rock
Ridge
Acquisition
    Source
Acquisition
        Kimmeridge
Mineral
Fund L.P.
(DPM
Predecessor)
        Falcon
Minerals
Corporation
         
                                                                       
    (In thousands, except per share data)

Revenue:

      A       B       C                    

Oil, natural gas and natural gas liquids revenues

  $ 118,548     $ 4,105     $ 10,328     $ 19,776     $         $ 152,757       $ 72,838     $ (1,970   J   $ 223,625    

Lease bonus and other income

    2,040         925       71           3,036           (227   D     4,779    
    —                         1,970     J    

Commodity derivatives losses

        (1,125       1,125     E     —           (4,830     4,830     J     —      
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

 

 

     

 

 

   

Total revenue

    120,588       4,105       10,128       19,847       1,125         155,793         68,008       4,603         228,404    
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

 

 

     

 

 

   

Operating Expenses:

                         

Management fees to affiliates

    7,480                 7,480     I           7,480    

Depreciation, depletion and amortization

    40,906         3,366         13,370     H     57,642         15,233       2,007     H     74,595    
                      (287   D    

General and administrative

    4,143         1,314             5,457         14,130       (373   D     48,914    
                      25,000     F    
                      4,700     G    

General and administrative — affiliates

    8,855                 8,855               8,855    

Severance and ad valorem taxes

    6,858       247       276       1,339           8,720         3,935           12,655    

Marketing and transportation

                    1,752           1,752    

Deferred offering costs write-off

    2,396                 2,396               2,396    
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

 

 

     

 

 

   

Total operating expenses

    70,638       247       4,956       1,339       13,370         90,550         35,050       31,047         156,647    
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

 

 

     

 

 

   

Net income (loss) from

operations

    49,950       3,858       5,172       18,508       (12,245       65,243         32,958       (26,444       71,757    

Other income (expense):

                         

Other income (expense)

      —                 —           517           517    

Interest income (expense), net

    (1,893       (88           (1,981       (1,924         (3,905  

Commodity derivatives losses

                      (4,830   J     (4,830  
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

 

 

     

 

 

   

Total other income (expense)

    (1,893     —         (88     —         —           (1,981       (1,407     (4,830       (8,218  
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

 

 

     

 

 

   

Net income before income tax expense

    48,057       3,858       5,084       18,508       (12,245       63,262         31,551       (31,274       63,539    

Income tax (expense) benefit

    (562       27             (535       (4,059     (9,386   K     (13,980  
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

 

 

     

 

 

   

Net income

  $ 47,495     $ 3,858     $ 5,111     $ 18,508     $ (12,245     $ 62,727       $ 27,492     $ (40,660     $ 49,559    
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

 

 

     

 

 

   

Less net income attributable to temporary equity

                      42,672     L     42,672    

Less net income attributable to non-controlling interests

    18,781                 18,781         14,336       (33,117   L     —      
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

 

 

     

 

 

   

Net income attributable to Desert Peak Minerals Inc.

  $ 28,714     $ 3,858     $ 5,111     $ 18,508     $ (12,245     $ 43,946       $ 13,156     $ (50,215     $ 6,887    
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

 

 

     

 

 

   

Net Income per Common Share

                         

Basic

                    0.28           0.55     M

Diluted

                    0.28           0.55     M

Weighted Average Common Shares Outstanding

                         

Basic

                    46,321           11,580     M

Diluted

                    46,321           11,580     M

 

7


Notes to unaudited pro forma condensed consolidated combined financial statements

 

1.

Basis of Presentation, the Offering and Reorganization

The pro forma financial statements have been derived from the historical financial statements of KMF and Falcon. The pro forma financial statements contain certain reclassification adjustments to (i) conform the historical KMF financial statement presentation to Falcon’s financial statement presentation and (ii) conform certain of Falcon’s historical amounts to KMF’s financial statement presentation. The pro forma condensed consolidated combined balance sheet as of March 31, 2022 gives effect to the Transactions as if they had occurred on March 31, 2022. The Desert Peak Acquisitions are reflected in the historical consolidated balance sheet of KMF as of March 31, 2022, and, as such, no pro forma adjustments are made for such transactions in the unaudited pro forma condensed consolidated combined balance sheet. The unaudited pro forma condensed consolidated combined statements of operations for the three months ended March 31, 2022 and for the year ended December 31, 2021 give effect to the Transactions as if they had occurred on January 1, 2021.

The pro forma financial statements reflect pro forma adjustments that are based on available information and certain assumptions that management believes are reasonable. However, actual results may differ from those reflected in these statements. In management’s opinion, all adjustments known to date that are necessary to present fairly the pro forma information have been made. The pro forma financial statements do not purport to represent what the Post-Combination Company’s financial position or results of operations would have been if the Transactions had actually occurred on the dates indicated above, nor are they indicative of the Post-Combination Company’s future financial position or results of operations.

These pro forma financial statements should be read in conjunction with the historical financial statements, and related notes thereto, of KMF and Falcon for the periods presented, which are included or incorporated by reference in this Proxy Statement.

 

2.

Unaudited Pro Forma Condensed Consolidated Combined Balance Sheet

Transaction Adjustments

 

  A.

Reflects the elimination of assets and liabilities included in the balance sheet of KMF related to the water business of KMF and KMF Water, LLC that will not be included in the Post-Combination Company.

 

  B.

Unless otherwise noted, the adjustments reflect the acquisition method of accounting with Desert Peak as the accounting acquirer of Falcon. Under the acquisition method of accounting, the purchase price is allocated to the identifiable tangible and intangible assets acquired and liabilities assumed based on their respective fair values, with any excess purchase price (if applicable) allocated to goodwill. Desert Peak has not completed the detailed valuation studies necessary to compute the fair value estimates of Falcon’s assets acquired and liabilities assumed and the related allocations of purchase price, nor has it identified all adjustments necessary to conform Falcon’s accounting policies to Desert Peak’s accounting policies. The preliminary estimation of the fair values of the Falcon assets was performed as of June 7, 2022. A final determination of the fair value of the Falcon assets and liabilities will be based on the actual net assets and liabilities of Falcon that existed as of the Closing Date. The value of the consideration given by Desert Peak will be based on the closing price of the Class A Common Stock on the Closing Date. The pro forma adjustments included herein may be revised as additional information becomes available and as additional analyses are performed. The final purchase price allocation may be different than that reflected in the preliminary pro forma purchase price allocation presented herein, and this difference may be material. The pro forma purchase price allocation is preliminary and was based on an estimate of the fair values of the tangible and intangible assets and liabilities related to Falcon and the closing price of the Class A Common Stock of $29.12 on June 7, 2022.

 

8


Notes to unaudited pro forma condensed consolidated combined financial statements—Continued

 

The following table summarizes the preliminary estimate of the purchase price (in thousands, except per share data):

 

Common Stock — issued and outstanding as of March 31, 2022(1):

     21,624  

Class A Common Stock price(1)

   $ 29.12  
  

 

 

 

Total consideration and fair value

   $ 629,676  
  

 

 

 

 

 

(1)

The final purchase price is based on the fair value of the issued and outstanding shares of Common Stock as of the Closing Date and the closing price of the Class A Common Stock on the Closing Date.

The following table summarizes the allocation of the preliminary estimate of the purchase price to the assets acquired and liabilities assumed (in thousands):

 

Falcon fair values:

  

Current assets

   $ 15,621  

Unproved oil and gas properties(1)

     429,534  

Proved oil and gas properties

     200,773  

Property and equipment

     296  

Deferred tax assets

     35,410  

Other long-term assets

     1,344  

Current liabilities

     (6,662

Long-term debt

     (38,000

Other long-term liabilities

     (8,640
  

 

 

 

Total consideration and fair value

   $ 629,676  
  

 

 

 

 

 

(1)

The fair market value mark up of Falcon’s unproved oil and gas properties is primarily attributable to (i) an increase in current commodity prices relative to commodity prices at the time Falcon booked its proved and unproved properties and (ii) the different methodologies used by Falcon and Desert Peak to book proved undeveloped reserves that result in a significant amount of Falcon’s proved undeveloped reserves and proved properties being booked by the Post-Combination Company as unproved reserves and unproved properties.

 

  C.

Represents the impact of one-time, nonrecurring transaction costs associated with the Merger Transactions. These transaction costs are based on preliminary estimates, and the final amounts and the resulting effect on Desert Peak’s financial position may differ significantly. These incremental costs are not yet reflected in the historical March 31, 2022 unaudited consolidated balance sheets of Falcon and KMF, but are reflected in the unaudited pro forma condensed consolidated combined balance sheet as an increase to accounts payable and accrued expenses as they will be expensed by Falcon and Desert Peak as incurred.

 

  D.

Represents the grant and vesting of one-time restricted stock units to each of the Post-Combination Company’s executive officers in connection with the Merger under the Incentive Plan. For a description of these awards, please see “Proposal No. 5 (Incentive Plan Proposal)” in the Proxy Statement.

 

  E.

The historical financial statements of the Post-Combination Company following the reverse merger will become those of Desert Peak (the accounting acquirer). As such, the adjustments represent: (i) the elimination of Falcon’s historical equity; and (ii) the retroactive restatement (recapitalization) of KMF’s equity structure to reflect that of Falcon (the legal acquirer) subsequent to the Merger Transactions. Interests attributable to shares of Class C Common Stock and Partnership Units will be classified as temporary equity in the Post-Combination Company due to the cash redemption features of these instruments. For a description of the cash redemption features of the Partnership Units, please see “The Merger Agreement—Amendment to Falcon OpCo Partnership Agreement” in the Proxy Statement.

 

  F.

Represents the reclassification of KMF’s non-controlling interest that will be classified as temporary equity due to the cash redemption features of the Class C Common Stock and Partnership Units in conjunction with the Merger Transactions. For a description of the cash redemption features of the Partnership Units, please see “The Merger Agreement — Amendment to Falcon OpCo Partnership Agreement” in the Proxy Statement.

 

9


Notes to unaudited pro forma condensed consolidated combined financial statements—Continued

 

  G.

Represents the increase in net assets as a result of the purchase price allocation, allocated between temporary equity and additional paid in capital, based on the percentage ownership split between holders of Class A Common Stock and Class C Common Stock, less the par value of new Class C Common Stock issued in the Merger as shown below.

 

     Post-Reverse
Stock Split
 

New Class C Common Stock

     58,750,000  

Additional Consideration

     3,155,339  

Total Class C Shares

     61,905,339  

Par value of new Class C Shares ($0.0001 per share)

   $ 6,191  

The increase in net assets as a result of the purchase price allocation, which can be attributed shares of Class C Common Stock will be classified into temporary equity due to the cash redemption features of the Class C Common Stock and Partnership Units; the increase allocable to Class A Common Stock will be classified to additional paid in capital. For a description of the cash redemption features of the Partnership Units, please see “The Merger Agreement — Amendment to Falcon OpCo Partnership Agreement” in the Proxy Statement. Below is the pro forma ownership of the Post-Combination Company after giving effect to the Merger Transactions, as well as the ownership by share class.

 

     Shares at Closing
(Post-Reverse
Stock Split)
     Percent
Ownership
 

Falcon Stockholders — Class A

     11,776,555        14

Falcon Stockholders — Class C

     9,846,946        12
  

 

 

    

Total Falcon Stockholders

     21,623,501        26
  

 

 

    

Desert Peak Stockholders — Class C

     61,905,340        74
  

 

 

    

Total Shares

     83,528,841        100
  

 

 

    

Total Class A Shares

     11,776,555        14

Total Class C Shares

     71,752,286        86

 

3.

Unaudited Pro Forma Condensed Consolidated Combined Statement of Operations

Desert Peak Adjustments

 

  A.

Reflects oil and gas operations of properties acquired in the Chambers Acquisition.

 

  B.

Reflects the historical statement of operations of certain oil and gas properties acquired in the Rock Ridge Acquisition.

 

  C.

Reflects the historical statement of revenues and direct operating expenses of certain oil and gas properties acquired in the Source Acquisition.

Transaction Adjustments

 

  D.

Reflects the elimination of revenues and operating expenses included in the results of operations of KMF related to the water business of KMF and KMF Water, LLC that will not be included in the Post-Combination Company.

 

  E.

Reflects the elimination of the commodity derivative losses associated with the Rock Ridge Acquisition. In accordance with the terms of the related purchase and sale agreement, the seller was obligated to terminate the derivative contracts prior to the closing of the Rock Ridge Acquisition.

 

  F.

Represents the impact of one-time, nonrecurring transaction costs associated with the Merger Transactions. These transaction costs are based on preliminary estimates, and the final amounts and the resulting effect on Desert Peak’s financial position may differ significantly. These incremental costs are only partially reflected in the historical consolidated statements of operations of Falcon and KMF for the three months ended March 31, 2022 and for the year ended December 31, 2021, but are reflected in the unaudited pro forma condensed consolidated statement of operations as an increase to general and administrative expense as they will be expensed by Falcon and Desert Peak as incurred.

 

10


Notes to unaudited pro forma condensed consolidated combined financial statements—Continued

 

  G.

Represents the grant and vesting of one-time restricted stock units to each of the Post-Combination Company’s executive officers in connection with the Merger under the Incentive Plan. For a description of these awards, please see “Proposal No. 5 (Incentive Plan Proposal)” in the Proxy Statement.

 

  H.

Reflects the pro forma impact to depletion expense associated with the change in fair value adjustment to oil and gas properties as a result of the Merger Agreement, Chambers Acquisition, Rock Ridge Acquisition and Source Acquisition. Pro forma depletion expense was calculated on a consolidated basis as though all such properties were owned for the entire period. This number was then offset by the historical depletion expense related to Falcon, KMF and the Rock Ridge Acquisition presented in the in the Falcon, KMF and Rock Ridge Acquisition columns, respectively, in the pro forma statement of operations, and the remaining amount was included as an Acquisition Adjustment on the face of the pro forma statement of operations. There is no historical depletion expense related to the Chambers Acquisition or Source Acquisition. The adjustment reflected under Transaction Adjustments was calculated using the units-of-production method under the successful efforts method of accounting (in thousands).

For the three months ended March 31, 2022

 

Depletion expense related to the fair value of the oil and gas properties of KMF and those acquired in the Merger, Chambers Acquisition, Rock Ridge Acquisition and Source Acquisition

   $ 14,504  

Less KMF historical depletion expense

     (15,238
  

 

 

 

DPM Predecessor Transaction Adjustments to depletion expense

   $ (734
  

 

 

 

Depletion expense related to the fair value of the oil and gas properties of Falcon

   $ 3,927  

Less Falcon historical depletion expense

     (3,424
  

 

 

 

Transaction Adjustments to depletion expense

   $ 503  
  

 

 

 

For the year ended December 31, 2021

 

Depletion expense related to the fair value of the oil and gas properties of KMF and those acquired in the Merger, Chambers Acquisition, Rock Ridge Acquisition and Source Acquisition

   $ 57,041  

Less KMF historical depletion expense

     (40,318

Less Rock Ridge historical depletion expense

     (3,353
  

 

 

 

DPM Predecessor Transaction Adjustments to depletion expense

   $ 13,370  
  

 

 

 

Depletion expense related to the fair value of the oil and gas properties of Falcon

   $ 17,240  

Less Falcon historical depletion expense

     (15,233
  

 

 

 

Transaction Adjustments to depletion expense

   $ 2,007  
  

 

 

 

 

  I.

Reflects the management fee expenses of KMF that were paid as compensation for services rendered in the management of the partnership. The management fee expenses represent the charge for managing the investment fund and did not include general and administrative expenses related to operating the business. The administrative expenses incurred by and reimbursed to management are presented in the general and administrative line item on the consolidated statement of operations. While a pro forma adjustment has not been made to eliminate the management fee expenses, the Company will not incur any management fees after completion of the Merger Transactions.

 

  J.

Reflects a pro forma adjustment to reclassify lease bonus and other income and commodity derivatives losses of Falcon to conform to Desert Peak’s presentation.

 

  K.

Reflects estimated income tax provision associated with Desert Peak’s historical results of operations assuming its earnings had been subject to federal and state income tax as a subchapter C corporation using a blended statutory rate of 22% for the period noted. This rate is inclusive of U.S. federal and state taxes. The calculation of future net income tax expense is performed on a year-by-year basis by taking into account each year’s projected revenues, operating expenses, depreciation, depletion, and other factors in arriving at each year’s tax outflow. As such, the effective rate utilized in this calculation can differ from the blended statutory rate.

 

11


Notes to unaudited pro forma condensed consolidated combined financial statements—Continued

 

  L.

Reflects the elimination of net income attributable to non-controlling interest of KMF and Falcon historical consolidated financial statements, as the non-controlling interest will not exist subsequent to the Falcon Merger Transactions. In addition, management estimated the net income attributable to the Class C Common Stock that will be classified as temporary equity on the Post-Combination Company’s consolidated balance sheet subsequent to the Merger Transactions.

 

  M.

Reflects basic and diluted loss per common shares of Class A Common Stock as shown below for the applicable period, computed using the two-class method (in thousands, except per share data):

For the three months ended March 31, 2022

 

Numerator:

  

Net income attributable to Desert Peak

   $ 2,187  

Less: Earnings allocated to participating securities

     (181
  

 

 

 

Net income attributable to common stockholders — basic

   $ 2,006  
  

 

 

 

Plus: Net income attributable to temporary equity(1)

     —    

Net income attributable to common stockholders — diluted

   $ 2,006  
  

 

 

 

Denominator(1):

  

Weighted average shares outstanding — basic

     11,762  

Effect of dilutive securities(1)

     —    
  

 

 

 

Weighted average shares outstanding — diluted

     11,762  
  

 

 

 

Net income per common share — basic

   $ 0.17  

Net income per common share — diluted

   $ 0.17  

 

(1)

For the three months ended March 31, 2022, Class C common stock was not included in the calculation of diluted earnings per share as the effect would have been antidilutive.

For the year ended December 31, 2021

 

Numerator:

  

Net income attributable to Desert Peak

   $ 6,887  

Less: Earnings allocated to participating securities

     (565
  

 

 

 

Net income attributable to common stockholders — basic

   $ 6,322  
  

 

 

 

Plus: Net income attributable to temporary equity(1)

     —    

Net income attributable to common stockholders — diluted

   $ 6,322  
  

 

 

 

Denominator(1):

  

Weighted average shares outstanding — basic

     11,580  

Effect of dilutive securities(1)

     —    
  

 

 

 

Weighted average shares outstanding — diluted

     11,580  
  

 

 

 

Net income per common share — basic

   $ 0.55  

Net income per common share — diluted

   $ 0.55  

 

(1)

For the year ended December 31, 2021, Class C common stock was not included in the calculation of diluted earnings per share as the effect would have been antidilutive.

4. Supplementary Disclosure of Oil and Natural Gas Operations

The following tables present the estimated pro forma proved reserve information as of December 31, 2021, along with a summary of changes in quantities of remaining proved reserves during the year ended December 31, 2021.

The following estimated pro forma reserve information is not necessarily indicative of the results that might have occurred had the Transactions been completed on December 31, 2021 and is not intended to be a projection of future results. Future results may vary significantly from the results reflected because of various factors, including those described under “Risk Factors.”

 

12


Notes to unaudited pro forma condensed consolidated combined financial statements—Continued

 

     Balance,
December 31,
2020
     Revisions     Extensions      Acquisition
of reserves
     Divestiture
of reserves
    Production     Balance,
December 31,
2021
 

Kimmeridge Mineral Fund, LP

                 

Oil (MBbls)

     5,075        180       610        7,240        —         (1,261     11,844  

Natural Gas (MMcf)

     23,402        6,531       1,991        19,165        —         (4,746     46,343  

Natural Gas Liquids (MBbls)

     2,825        405       216        2,076        —         (499     5,023  
  

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Total (MBOE)

     11,800        1,674       1,158        12,511        —         (2,551     24,592  
  

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Chambers Acquisition

                 

Oil (MBbls)

     775        (5     —          —          (713     (57     —    

Natural Gas (MMcf)

     2,694        (447     —          —          (2,108     (139     —    

Natural Gas Liquids (MBbls)

     326        48       —          —          (349     (25     —    
  

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Total (MBOE)

     1,550        (32     —          —          (1,413     (105     —    
  

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Rock Ridge Acquisition

                 

Oil (MBbls)

     3,564        (1,781     —          —          (1,620     (163     —    

Natural Gas (MMcf)

     8,132        (3,551     —          —          (4,095     (486     —    

Natural Gas Liquids (MBbls)

     1,325        (834     —          —          (438     (53     —    
  

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Total (MBOE)

     6,244        (3,207     —          —          (2,740     (297     —    
  

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Source Acquisition

                 

Oil (MBbls)

     1,515        347       —          —          (1,585     (277     —    

Natural Gas (MMcf)

     4,033        847       —          —          (4,423     (457     —    

Natural Gas Liquids (MBbls)

     359        69       —          —          (394     (34     —    
  

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Total (MBOE)

     2,546        557       —          —          (2,716     (387     —    
  

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Falcon Minerals Corporation

                 

Oil (MBbls)

     9,742        (1,571     326        22        —         (756     7,763  

Natural Gas (MMcf)

     48,536        (3,109     1,777        34        —         (3,801     43,437  

Natural Gas Liquids (MBbls)

     2,186        159       122        5        —         (230     2,242  
  

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Total (MBOE)

     20,017        (1,930     744        33        —         (1,620     17,245  
  

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Pro Forma

                 

Oil (MBbls)

     20,671        (2,830     936        7,262        (3,918     (2,514     19,607  

Natural Gas (MMcf)

     86,797        271       3,768        19,199        (10,626     (9,629     89,780  

Natural Gas Liquids (MBbls)

     7,021        (153     338        2,081        (1,181     (841     7,265  
  

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

Total (MBOE)

     42,157        (2,938     1,902        12,544        (6,869     (4,960     41,837  
  

 

 

    

 

 

   

 

 

    

 

 

    

 

 

   

 

 

   

 

 

 

 

     Proved Developed and Undeveloped Reserves  
     Developed
as of

December 31,
2020
     Undeveloped
as of
December 31,
2020
     Balance,
December 31,
2020
     Developed
as of

December 31,
2021
     Undeveloped
as of
December 31,
2021
     Balance,
December 31,
2021
 

Kimmeridge Mineral Fund, LP

                 

Oil (MBbls)

     3,731        1,344        5,075        9,285        2,559        11,844  

Natural Gas (MMcf)

     19,505        3,897        23,402        40,747        5,596        46,343  

Natural Gas Liquids (MBbls)

     2,352        473        2,825        4,417        606        5,023  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total (MBOE)

     9,334        2,467        11,800        20,494        4,098        24,592  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Chambers Acquisition

                 

Oil (MBbls)

     596        179        775        —          —          —    

Natural Gas (MMcf)

     2,088        606        2,694        —          —          —    

Natural Gas Liquids (MBbls)

     253        73        326        —          —          —    
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total (MBOE)

     1,196        354        1,550        —          —          —    
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Rock Ridge Acquisition

                 

Oil (MBbls)

     1,469        2,095        3,564        —          —          —    

Natural Gas (MMcf)

     3,723        4,409        8,132        —          —          —    

Natural Gas Liquids (MBbls)

     599        726        1,325        —          —          —    
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total (MBOE)

     2,688        3,556        6,244        —                  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Source Acquisition

                 

Oil (MBbls)

     1,060        455        1,515        —          —          —    

Natural Gas (MMcf)

     3,244        789        4,033        —          —          —    

Natural Gas Liquids (MBbls)

     289        70        359        —          —          —    
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total (MBOE)

     1,890        656        2,546        —          —          —    
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Falcon Minerals Corporation

                 

Oil (MBbls)

     3,291        6,451        9,742        2,738        5,025        7,763  

Natural Gas (MMcf)

     19,755        28,781        48,536        19,098        24,339        43,437  

 

13


Notes to unaudited pro forma condensed consolidated combined financial statements—Continued

 

     Proved Developed and Undeveloped Reserves  
     Developed
as of

December 31,
2020
     Undeveloped
as of
December 31,
2020
     Balance,
December 31,
2020
     Developed
as of

December 31,
2021
     Undeveloped
as of
December 31,
2021
     Balance,
December 31,
2021
 

Natural Gas Liquids (MBbls)

     1,164        1,022        2,186        1,183        1,059        2,242  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total (MBOE)

     7,747        12,270        20,017        7,104        10,141        17,245  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Pro Forma

                 

Oil (MBbls)

     10,147        10,524        20,671        12,023        7,584        19,607  

Natural Gas (MMcf)

     48,315        38,482        86,797        59,845        29,935        89,780  

Natural Gas Liquids (MBbls)

     4,657        2,364        7,021        5,600        1,665        7,265  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total (MBOE)

     22,855        19,303        42,157        27,598        14,239        41,837  
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Standardized Measure of Discounted Future Cash Flows

The following pro forma standardized measure of the discounted net future cash flows and changes applicable to KMF’s proved reserves reflect the effect of income taxes assuming KMF’s standardized measure had been subject to federal and state income tax as a subchapter C corporation. The future cash flows are discounted at 10% per year and assume continuation of existing economic conditions.

The standardized measure of discounted future net cash flows, in management’s opinion, should be examined with caution. The basis for this table is the reserve studies audited by independent petroleum engineering consultants, which contain imprecise estimates of quantities and rates of production of reserves. Revisions of previous year estimates can have a significant impact on these results. Also, estimates of new discoveries and undeveloped locations are more imprecise than estimates of established proved producing oil and gas properties. Accordingly, these estimates are expected to change as future information becomes available. Therefore, the standardized measure of discounted future net cash flows is not necessarily indicative of the fair value of KMF’s proved oil and natural gas properties.

The data presented should not be viewed as representing the expected cash flows from or current value of existing proved reserves since the computations are based on a large number of estimates and assumptions. Reserve quantities cannot be measured with precision and their estimation requires many judgmental determinations and frequent revisions. Actual future prices and costs are likely to be substantially different from the prices and costs utilized in the computation of reported amounts.

The pro forma standardized measure of discounted estimated future net cash flows was as follows as of December 31, 2021 (in thousands):

 

     KIMMERIDGE
MINERAL FUND, LP
     FALCON
MINERALS
CORPORATION
     CORPORATE
REORGANIZATION
     PRO FORMA  

Future oil and natural gas sales

   $ 1,068,652      $ 708,450      $ —        $ 1,777,102  

Future production costs

     (90,137      (51,256      —          (141,393

Future income tax expense

     (5,302      (42,787      (36,186      (84,275
  

 

 

    

 

 

    

 

 

    

 

 

 

Future net cash flows

     973,213        614,407        (36,186      1,551,434  
  

 

 

    

 

 

    

 

 

    

 

 

 

10% annual discount

     (437,910      (267,005      14,938        (689,977
  

 

 

    

 

 

    

 

 

    

 

 

 

Standardized measure of discounted future net cash flows

   $ 535,303      $ 347,402      $ (21,248    $ 861,457  
  

 

 

    

 

 

    

 

 

    

 

 

 

Pro forma income tax expense is calculated using the estimated statutory rate of 22%. The pro forma future income tax expense, as calculated, is lower than the statutory rate due to the tax basis related to the acquired properties.

 

14


Notes to unaudited pro forma condensed consolidated combined financial statements—Continued

 

The change in the pro forma standardized measure of discounted estimated future net cash flows were as follows for the year ended December 31, 2021 (in thousands):

 

    KIMMERIDGE
MINERAL
FUND, LP
    CHAMBERS
ACQUISITION
    ROCK RIDGE
ACQUISITION
    SOURCE
ACQUISITION
    FALCON
MINERALS
CORPORATION
    CORPORATE
REORGANIZA-
TION
    PRO FORMA  

Balance at the beginning of the period

  $ 123,559     $ 17,838     $ 72,639     $ 39,965     $ 251,812     $ —       $ 505,813  

Net change in prices and production costs

    119,993       12,877       35,964       28,437       186,943       —         384,214  

Sales, net of production costs

    (111,691     (3,858     (10,054     (18,437     (65,181     —         (209,221

Extensions and discoveries

    29,853       —         —         —         15,048       —         44,901  

Acquisitions of reserves

    326,192       —         —         —         1,026       —         327,218  

Divestiture of reserves

    —         (30,424     (68,318     (69,721     —         —         (168,463

Revisions of previous quantity estimates

    43,843       —         —         —         (29,572     —         14,271  

Net change in income taxes

    (2,205     —         —         —         (20,810     (21,248     (44,263

Accretion of discount

    12,426       1,784       7,264       3,997       25,553       —         51,024  

Changes in timing and other

    (6,667     1,783       (37,495     15,759       (17,417     —         (44,037
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Balance at the end of the period

  $ 535,303     $ —       $ —       $ —       $ 347,402     $ (21,248   $ 861,457  
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

15

Exhibit 99.7

RISK FACTORS

Risk Factors Related to Desert Peak

Risks Related to Desert Peak’s Business

Desert Peak’s producing properties are located in the Permian Basin, making it vulnerable to risks associated with operating in a single geographic area.

All of Desert Peak’s producing properties are currently geographically concentrated in the Permian Basin. As a result of this concentration, Desert Peak may be disproportionately exposed to the impact of regional supply and demand factors, delays or interruptions of production from wells in this area caused by governmental regulation, processing or transportation capacity constraints, availability of equipment, facilities, personnel or services market limitations, natural disasters, adverse weather conditions, plant closures for scheduled maintenance or interruption of the processing or transportation of crude oil, natural gas or NGLs. In addition, the effect of fluctuations on supply and demand may become more pronounced within specific geographic crude oil and natural gas producing areas such as the Permian Basin, which may cause these conditions to occur with greater frequency or magnify the effects of these conditions. Due to the concentrated nature of Desert Peak’s portfolio of properties, a number of its properties could experience any of the same conditions at the same time, resulting in a relatively greater impact on its results of operations than they might have on other companies that have a more diversified portfolio of properties. Such delays or interruptions could have a material adverse effect on Desert Peak’s financial condition and results of operations.

As a result of Desert Peak’s exclusive focus on the Permian Basin, it may be less competitive than other companies in bidding to acquire assets that include properties both within and outside of that basin. Although Desert Peak is currently focused on the Permian Basin, it may from time to time evaluate and consummate the acquisition of asset packages that include ancillary properties outside of that basin, which may result in the dilution of its geographic focus.

If the E&P operators of Desert Peak’s properties suspend its right to receive royalty payments due to title or other issues, Desert Peak’s business, financial condition, results of operations and cash flows may be adversely affected.

Desert Peak depends in part on acquisitions to grow its reserves, production and cash generated from operations. In connection with these acquisitions, record title to mineral and royalty interests are conveyed to Desert Peak or its subsidiaries by asset assignment, and Desert Peak or its subsidiaries become the record owner of these interests. Upon such a change in ownership of mineral interests, and at regular intervals pursuant to routine audit procedures at each of Desert Peak E&P operators otherwise at its discretion, the E&P operator of the underlying property has the right to investigate and verify the title and ownership of mineral and royalty

 

1


interests with respect to the properties it operates. If any title or ownership issues are not resolved to its reasonable satisfaction in accordance with customary industry standards, the E&P operator may suspend payment of the related royalty. If an E&P operator of Desert Peak’s properties is not satisfied with the documentation Desert Peak provide to validate Desert Peak’s ownership, such E&P operator may place Desert Peak’s royalty payment in suspense until such issues are resolved, at which time Desert Peak would receive in full payments that would have been made during the suspense period, without interest. Certain of Desert Peak’s E&P operators impose significant documentation requirements for title transfer and may keep royalty payments in suspense for significant periods of time. During the time that an E&P operator puts Desert Peak’s assets in pay suspense, Desert Peak would not receive the applicable mineral or royalty payment owed to Desert Peak from sales of the underlying oil or natural gas related to such mineral or royalty interest. If a significant amount of Desert Peak’s royalty interests are placed in suspense, its results of operations may be reduced significantly.

Title to the properties in which Desert Peak has an interest may be impaired by title defects.

Desert Peak is not required to, and under certain circumstances it may elect not to, incur the expense of retaining lawyers to examine the title to its royalty and mineral interests. In such cases, Desert Peak would rely upon the judgment of oil and gas lease brokers or landmen who perform the fieldwork in examining records in the appropriate governmental office before acquiring a specific royalty or mineral interest. The existence of a material title deficiency can render an interest worthless and can materially adversely affect Desert Peak’s results of operations, financial condition and cash flows. No assurance can be given that Desert Peak will not suffer a monetary loss from title defects or title failure. Additionally, undeveloped acreage has a greater risk of title defects than developed acreage. If there are any title defects in properties in which Desert Peak holds an interest, it may suffer a financial loss.

Desert Peak may experience delays in the payment of royalties and be unable to replace E&P operators that do not make required royalty payments, and it may not be able to terminate its leases with defaulting lessees if any of the E&P operators on those leases declare bankruptcy.

Desert Peak may experience delays in receiving royalty payments from its E&P operators, including as a result of delayed division orders received by its E&P operators. A failure on the part of the E&P operators to make royalty payments typically gives Desert Peak the right to terminate the lease, repossess the property and enforce payment obligations under the lease. If Desert Peak repossessed any of its properties, it would seek a replacement E&P operator. However, Desert Peak might not be able to find a replacement E&P operator and, if it did, it might not be able to enter into a new lease on favorable terms within a reasonable period of time. In addition, the outgoing E&P operator could be subject to a proceeding under Title 11 of the United States Code (the “Bankruptcy Code”), in which case Desert Peak’s right to enforce or terminate the lease for any defaults, including non-payment, may be substantially delayed or otherwise impaired. In general, in a proceeding under the Bankruptcy Code, the bankrupt E&P operator would have a substantial period of time to decide whether to ultimately reject or assume the lease, which could prevent the execution of a new lease or the assignment of the existing lease to another E&P operator. For example, certain of Desert Peak’s E&P operators have recently commenced bankruptcy proceedings under the Bankruptcy Code and their future operations and ability to make royalty payments to us may be adversely affected by such proceedings. In the event that the E&P operator rejected the lease, Desert Peak’s ability to collect amounts owed would be substantially delayed, and its ultimate recovery may be only a fraction of the amount owed or nothing. In addition, if Desert Peak is able to enter into a new lease with a new E&P operator, the replacement E&P operator may not achieve the same levels of production or sell crude oil or natural gas at the same price as the E&P operator it replaced.

 

2


Desert Peak depends on various unaffiliated E&P operators for all of the exploration, development and production on the properties underlying its mineral and royalty interests. Substantially all of Desert Peak’s revenue is derived from royalty payments made by these E&P operators. A reduction in the expected number of wells to be drilled on Desert Peak’s acreage by these E&P operators or the failure of its E&P operators to adequately and efficiently develop and operate the wells on its acreage could have an adverse effect on its results of operations and cash flows.

Desert Peak’s assets consist of mineral and royalty interests. Because Desert Peak depends on third-party E&P operators for all of the exploration, development and production on its properties, it has little to no control over the operations related to its properties. For the year ended December 31, 2021, Desert Peak received revenue from 84 E&P operators, with approximately 73% coming from the top ten E&P operators on its properties, four of which each accounted for more than 10% of such royalty revenues. The failure of Desert Peak’s E&P operators to adequately or efficiently perform operations or an E&P operator’s failure to act in ways that are in Desert Peak’s best interests could reduce production and revenues. Furthermore, in response to the significant decrease in prices for crude oil during 2020, many of Desert Peak’s E&P operators substantially reduced their development activities in 2020. Generally, drilling and completion activity had not yet returned to pre-pandemic levels by the end of 2021. Additionally, certain investors have requested that operators adopt initiatives to return capital to investors, which could also reduce the capital available to Desert Peak’s E&P operators for investment in exploration, development and production activities. Desert Peak’s E&P operators may further reduce capital expenditures devoted to exploration, development and production on its properties in the future, which could negatively impact revenues it receives. The number of new wells drilled has decreased, and such slower development pace may continue in the future, especially as a consequence of the reductions in Desert Peak’s E&P operators’ capital expenditures. Moreover, over the last year, many of Desert Peak’s E&P operators have announced that they plan to drill fewer wells per section than previously anticipated, due in part to greater well-interference between parent and child wells than previously anticipated and an increased focus on overall capital efficiency in a low commodity price environment.

If production on Desert Peak’s mineral and royalty interests decreases due to decreased development activities, as a result of the low commodity price environment, limited availability of development capital, production-related difficulties or otherwise, Desert Peak’s results of operations may be adversely affected. For example, the amount of royalty payments Desert Peak received in 2020 from its E&P operators decreased due to the lower prices at which its E&P operators were able to sell production from its properties and reduced production activities by its E&P operators. Further, depressed commodity prices caused some of Desert Peak’s E&P operators to voluntarily shut in and curtail production from wells on its properties in 2020. Although most of these have come back online, an additional or extended period of depressed commodity prices may cause additional E&P operators to take similar action or even to plug and abandon marginal wells that otherwise may have been allowed to continue to produce for a longer period under more favorable pricing conditions, both of which would decrease the amount of royalty payments Desert Peak receives from its E&P operators. Desert Peak’s E&P operators are often not obligated to undertake any development activities other than those required to maintain their leases on Desert Peak’s acreage. In the absence of a specific contractual obligation, any development and production activities will be subject to their reasonable discretion (subject to certain implied obligations to develop imposed by the laws of some states). Desert Peak’s E&P operators could determine to drill and complete fewer wells on Desert Peak’s acreage than is currently expected. The success and timing of drilling and development activities on Desert Peak’s properties, and whether the E&P operators elect to drill any additional wells on Desert Peak’s acreage, depends on a number of factors that are largely outside of Desert Peak’s control, including:

 

   

the capital costs required for drilling activities by Desert Peak’s E&P operators, which could be significantly more than anticipated;

 

   

the ability of Desert Peak’s E&P operators to access capital;

 

   

prevailing commodity prices;

 

3


   

the availability of suitable drilling equipment, production and transportation infrastructure and qualified operating personnel;

 

   

the availability of storage for hydrocarbons, the E&P operators’ expertise, operating efficiency and financial resources;

 

   

approval of other participants in drilling wells;

 

   

the E&P operators’ expected return on investment in wells drilled on Desert Peak’s acreage as compared to opportunities in other areas;

 

   

the selection of technology;

 

   

the selection of counterparties for the marketing and sale of production;

 

   

and the rate of production of the reserves.

The E&P operators may elect not to undertake development activities, or may undertake these activities in an unanticipated fashion, which may result in significant fluctuations in Desert Peak’s results of operations and cash flows. Sustained reductions in production by the E&P operators on Desert Peak’s properties may also adversely affect Desert Peak’s results of operations and cash flows. Additionally, if an E&P operator were to experience financial difficulty, the E&P operator might not be able to pay its royalty payments or continue its operations, which could have a material adverse impact on Desert Peak’s cash flows.

Desert Peak’s future success depends on replacing reserves through acquisitions and the exploration and development activities of its E&P operators.

Producing crude oil and natural gas wells are characterized by declining production rates that vary depending upon reservoir characteristics and other factors. Desert Peak’s future crude oil, natural gas and NGL reserves and its E&P operators’ production thereof and Desert Peak’s cash flows are highly dependent on the successful development and exploitation of Desert Peak’s current reserves and its ability to successfully acquire additional reserves that are economically recoverable. Moreover, the production decline rates of Desert Peak’s properties may be significantly higher than currently estimated if the wells on its properties do not produce as expected. Desert Peak may also not be able to find, acquire or develop additional reserves to replace the current and future production of its properties at economically acceptable terms. Aside from acquisitions, Desert Peak has little to no control over the exploration and development of its properties. If Desert Peak is not able to replace or grow its oil, natural gas and NGL reserves, its business, financial condition and results of operations would be adversely affected.

Desert Peak’s failure to successfully identify, complete and integrate acquisitions of properties or businesses could materially and adversely affect its growth, results of operations and cash flows.

Desert Peak depends in part on acquisitions to grow its reserves, production and cash flows. Desert Peak’s decision to acquire a property will depend in part on the evaluation of data obtained from production reports and engineering studies, geophysical and geological analyses and seismic data, and other information, the results of which are often inconclusive and subject to various interpretations. The successful acquisition of properties requires an assessment of several factors, including:

 

   

recoverable reserves;

 

   

future crude oil, natural gas and NGL prices and their applicable differentials;

 

   

development plans;

 

   

operating costs Desert Peak’s E&P operators would incur to develop and operate the properties;

 

   

and potential environmental and other liabilities that E&P operators may incur.

 

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The accuracy of these assessments is inherently uncertain and Desert Peak may not be able to identify attractive acquisition opportunities. In connection with these assessments, Desert Peak performs a review of the subject properties that it believes to be generally consistent with industry practices, given the nature of its interests. Desert Peak’s review will not reveal all existing or potential problems, nor will it permit it to become sufficiently familiar with the properties to assess fully their deficiencies and capabilities. Inspections are often not performed on every well, and environmental problems, such as groundwater contamination, are not necessarily observable even when an inspection is undertaken. Even when problems are identified, the seller may be unwilling or unable to provide effective contractual protection against all or part of the problems. Even if Desert Peak does identify attractive acquisition opportunities, it may not be able to complete the acquisition or do so on commercially acceptable terms. Unless Desert Peak’s E&P operators further develop its existing properties, it will depend on acquisitions to grow its reserves, production and cash flow.

There is intense competition for acquisition opportunities in Desert Peak’s industry. Competition for acquisitions may increase the cost of, or cause Desert Peak to refrain from, completing acquisitions. Additionally, acquisition opportunities vary over time. For example, in connection with the COVID-19 pandemic and resulting market and commodity price challenges, Desert Peak’s acquisition activity saw a significant decline as it experienced a meaningful difference in sellers’ pricing expectations and the prices Desert Peak was willing to offer. Desert Peak’s ability to complete acquisitions is dependent upon, among other things, its ability to obtain debt and equity financing and, in some cases, regulatory approvals. Further, these acquisitions may be in geographic regions in which Desert Peak does not currently hold assets, which could result in unforeseen operating difficulties. In addition, if Desert Peak acquires interests in new states, it may be subject to additional and unfamiliar legal and regulatory requirements. Compliance with regulatory requirements may impose substantial additional obligations on Desert Peak and its management, cause it to expend additional time and resources in compliance activities and increase its exposure to penalties or fines for non-compliance with such additional legal requirements. Further, the success of any completed acquisition will depend on Desert Peak’s ability to integrate effectively the acquired business into its existing business. The process of integrating acquired businesses may involve unforeseen difficulties and may require a disproportionate amount of Desert Peak’s managerial and financial resources. In addition, potential future acquisitions may be larger and for purchase prices significantly higher than those paid for earlier acquisitions.

No assurance can be given that Desert Peak will be able to identify suitable acquisition opportunities, negotiate acceptable terms, obtain financing for acquisitions on acceptable terms or successfully acquire identified targets. Desert Peak’s failure to achieve consolidation savings, to integrate the acquired assets into its existing operations successfully or to minimize any unforeseen difficulties could materially and adversely affect its financial condition, results of operations and cash flows. The inability to effectively manage these acquisitions could reduce Desert Peak’s focus on subsequent acquisitions and current operations, which, in turn, could negatively impact its growth, results of operations and cash flows.

Desert Peak may acquire properties that do not produce as projected, and it may be unable to determine reserve potential, identify liabilities associated with such properties or obtain protection from sellers against such liabilities.

Acquiring crude oil, natural gas and NGL properties requires Desert Peak to assess reservoir and infrastructure characteristics, including recoverable reserves, development and operating costs and potential environmental and other liabilities. Such assessments are inexact and inherently uncertain. In connection with the assessments, Desert Peak performs a review of the subject properties, but such a review will not necessarily reveal all existing or potential problems. In the course of Desert Peak’s due diligence, it may not inspect every well or pipeline. Desert Peak cannot necessarily observe structural and environmental problems, such as pipe corrosion, when an inspection is made. Desert Peak may not be able to obtain contractual indemnities from the seller for liabilities created prior to its purchase of the property. Desert Peak may be required to assume the risk of the physical condition of the properties in addition to the risk that the properties may not perform in accordance with its expectations.

 

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Any acquisitions of additional mineral and royalty interests that Desert Peak completes will be subject to substantial risks.

Even if Desert Peak makes acquisitions that it believes will increase its cash generated from operations, these acquisitions may nevertheless result in a decrease in its cash flows. Any acquisition involves potential risks, including, among other things:

 

   

the validity of Desert Peak’s assumptions about estimated proved reserves, future production, prices, revenues, capital expenditures, the operating expenses and costs its E&P operators would incur to develop the minerals;

 

   

a decrease in Desert Peak’s liquidity by using a significant portion of its cash generated from operations or borrowing capacity to finance acquisitions;

 

   

a significant increase in Desert Peak’s interest expense or financial leverage if it incurs debt to finance acquisitions;

 

   

the assumption of unknown liabilities, losses or costs for which Desert Peak is not indemnified or for which any indemnity it receives is inadequate;

 

   

mistaken assumptions about the overall cost of equity or debt;

 

   

Desert Peak’s ability to obtain satisfactory title to the assets it acquires;

 

   

an inability to hire, train or retain qualified personnel to manage and operate Desert Peak’s growing business and assets;

 

   

and the occurrence of other significant changes, such as impairment of crude oil and natural gas properties, goodwill or other intangible assets, asset devaluation or restructuring charges.

Desert Peak’s E&P operators’ identified potential drilling locations are susceptible to uncertainties that could materially alter the occurrence or timing of their drilling.

The ability of Desert Peak’s E&P operators to drill and develop identified potential drilling locations depends on a number of uncertainties, including the availability of capital, construction of and limitations on access to infrastructure, inclement weather, regulatory changes and approvals, crude oil, natural gas and NGL prices, costs, drilling results and the availability of water. Further, Desert Peak’s E&P operators’ identified potential drilling locations are in various stages of evaluation, ranging from locations that are ready to drill to locations that will require substantial additional interpretation. The use of technologies and the study of producing fields in the same area will not enable Desert Peak’s E&P operators to know conclusively prior to drilling whether crude oil, natural gas or NGLs will be present or, if present, whether crude oil, natural gas or NGLs will be present in sufficient quantities to be economically viable. Even if sufficient amounts of crude oil or natural gas exist, Desert Peak’s E&P operators may damage the potentially productive hydrocarbon-bearing formation or experience mechanical difficulties while drilling or completing the well, possibly resulting in a reduction in production from the well or abandonment of the well. If Desert Peak’s E&P operators drill additional wells that they identify as dry holes in current and future drilling locations, their drilling success rate may decline and materially harm their business as well as that of Desert Peak.

There is no guarantee that the conclusions Desert Peak’s E&P operators draw from available data from the wells on Desert Peak’s acreage, more fully explored locations or producing fields will be applicable to their drilling locations. Further, initial production rates reported by Desert Peak’s or other E&P operators in the areas in which Desert Peak’s reserves are located may not be indicative of future or long-term production rates. Additionally, actual production from wells may be less than expected. For example, a number of E&P operators have recently announced that newer wells drilled close in proximity to already producing wells have produced less oil and gas than forecast. Because of these uncertainties, Desert Peak does not know if the potential drilling locations its E&P operators have identified will ever be drilled or if its E&P operators will be able to produce

 

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crude oil, natural gas or NGLs from these or any other potential drilling locations. As such, the actual drilling activities of Desert Peak’s E&P operators may materially differ from those presently identified, which could adversely affect Desert Peak’s business, results of operation and cash flows.

Finally, the potential drilling locations Desert Peak has identified are based on the geologic and other data available to it and its interpretation of such data. As a result, Desert Peak’s E&P operators may have reached different conclusions about the potential drilling locations on Desert Peak’s properties, and Desert Peak’s E&P operators control the ultimate decision as to where and when a well is drilled.

Desert Peak is unable to determine with certainty which E&P operators will ultimately operate its properties.

When Desert Peak evaluates acquisition opportunities and the likelihood of the successful and complete development of its properties, Desert Peak considers which companies it expects to operate its properties. Historically, many of Desert Peak’s properties have been operated by active, well-capitalized E&P operators that have expressed their intent to execute multi-year, pad-focused development programs. There is no guarantee, however, that such E&P operators will become or remain the E&P operators on Desert Peak’s properties or that their development plans will not change. To the extent Desert Peak’s E&P operators fail to perform at the levels projected or the E&P operator of Desert Peak’s properties or sell their working interests to, are merged with, or are acquired by, another E&P operator that lacks the same level of capitalization or experience, it could adversely affect Desert Peak’s business and expected cash flows.

Desert Peak relies on its E&P operators, third parties and government databases for information regarding its assets and, to the extent that information is incorrect or incomplete, Desert Peak’s financial and operational information and projections may be incorrect.

As an owner of mineral and royalty interests, Desert Peak relies on the E&P operators of the properties to notify it of information regarding production on its properties in a timely and complete manner, as well as the accuracy of information obtained from third parties and government databases. Desert Peak uses this information to evaluate its operations and cash flows, as well as to predict its expected production and possible future locations. To the extent Desert Peak does not timely receive this information or the information is incomplete or incorrect, Desert Peak’s results may be incorrect and its ability to project potential growth may be materially adversely affected. Furthermore, to the extent Desert Peak has to update any publicly disclosed results or projections made in reliance on this incorrect or incomplete information, investors could lose confidence in its reported financial information.

Desert Peak has completed numerous acquisitions of mineral and royalty interests for which separate financial information is not required or provided.

As of December 31, 2021, Desert Peak has completed 180 acquisitions of mineral and royalty interests that are not “significant” under Rule 3-05 of Regulation S-X (“Rule 3-05”). Therefore, Desert Peak is not required to, and has elected not to, provide separate historical financial information relating to those acquisitions. While these acquisitions are not individually or collectively significant for purposes of Rule 3-05, they have or will have an impact on Desert Peak’s financial results and their aggregated effect on its business and results of operations may be material.

Acquisitions and Desert Peak’s E&P operators’ development of Desert Peak’s leases will require substantial capital, and Desert Peak and Desert Peak’s E&P operators may be unable to obtain needed capital or financing on satisfactory terms or at all.

The crude oil and natural gas industry is capital intensive. Desert Peak makes and may continue to make substantial capital expenditures in connection with the acquisition of mineral and royalty interests. To date, Desert Peak has financed capital expenditures primarily with funding from capital contributions and cash generated by operations. In addition, Desert Peak expects to finance capital expenditures with borrowings under its revolving credit facility.

 

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In the future, Desert Peak may need capital in excess of the amounts it retains in its business or borrows under its revolving credit facility. The level of borrowing base available under Desert Peak’s revolving credit facility is largely based on its estimated proved reserves and its lenders’ price decks and underwriting standards in the reserve-based lending space and will be reduced to the extent commodity prices decrease or remain depressed, underwriting standards tighten or the lending syndication market is not sufficiently liquid to obtain lender commitments to a full borrowing base in an amount appropriate for Desert Peak’s assets. Furthermore, Desert Peak cannot assure you that it will be able to access other external capital on terms favorable to it or at all. For example, a significant decline in prices for crude oil and broader economic turmoil may adversely impact Desert Peak’s ability to secure financing in the capital markets on favorable terms. Additionally, Desert Peak’s ability to secure financing or access the capital markets could be adversely affected if financial institutions and institutional lenders elect not to provide funding for fossil fuel energy companies in connection with the adoption of sustainable lending initiatives or are required to adopt policies that have the effect of reducing the funding available to the fossil fuel sector. If Desert Peak is unable to fund its capital requirements, Desert Peak may be unable to complete acquisitions, take advantage of business opportunities or respond to competitive pressures, any of which could have a material adverse effect on its results of operation and free cash flow.

Most of Desert Peak’s E&P operators are also dependent on the availability of external debt, equity financing sources and operating cash flows to maintain their drilling programs. If those financing sources are not available to the E&P operators on favorable terms or at all, then Desert Peak expects the development of its properties to be adversely affected. If the development of Desert Peak’s properties is adversely affected, then revenues from Desert Peak’s mineral and royalty interests may decline.

The development of Desert Peak’s PUDs may take longer and may require higher levels of capital expenditures from the E&P operators of Desert Peak’s properties than Desert Peak or they currently anticipate.

As of December 31, 2021, approximately 17% of Desert Peak’s total estimated proved reserves were PUDs and may not be ultimately developed or produced by the E&P operators of its properties. Recovery of PUDs requires significant capital expenditures and successful drilling operations by the E&P operators of Desert Peak’s properties. The reserve data included in the reserve report of Desert Peak’s independent petroleum engineer assume that substantial capital expenditures by the E&P operators of Desert Peak’s properties are required to develop such reserves. Desert Peak typically does not have access to the estimated costs of development of these reserves or the scheduled development plans of its E&P operators. Even when Desert Peak does have such information, Desert Peak cannot be certain that the estimated costs of the development of these reserves are accurate, that its E&P operators will develop the properties underlying its mineral and royalty interests as scheduled or that the results of such development will be as estimated. The development of such reserves may take longer and may require higher levels of capital expenditures from the E&P operators than Desert Peak anticipates. Delays in the development of Desert Peak’s reserves, increases in costs to drill and develop such reserves or decreases or continued volatility in commodity prices will reduce the future net revenues of its estimated PUDs and may result in some projects becoming uneconomical for the E&P operators of its properties. In addition, delays in the development of reserves could force Desert Peak to reclassify certain of its proved reserves as PUDs.

The widespread outbreak of an illness, pandemic (like COVID-19) or any other public health crisis may have material adverse effects on Desert Peak’s business, financial position, results of operations and/or cash flows.

Desert Peak faces risks related to the outbreak of illnesses, pandemics and other public health crises that are outside of its control, and could significantly disrupt its operations and adversely affect its financial condition. For example, the COVID-19 pandemic has caused a disruption to the oil and natural gas industry and to Desert Peak’s business. The COVID-19 pandemic has negatively impacted the global economy, disrupted global supply chains, reduced global demand for oil and gas, and created significant volatility and disruption of financial and commodity markets. Furthermore, the COVID-19 pandemic has affected Desert Peak’s operations by

 

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(i) rendering Desert Peak’s personnel unable to access company facilities for an extended period of time, (ii) contributing to a steep decline in commodities prices in 2020, which has reduced activity by Desert Peak’s operators and the amounts of royalty payments Desert Peak receives, (iii) causing some of Desert Peak’s operators to temporarily shut in or curtail production from wells and (iv) reducing the level of potential acquisition opportunities, limiting Desert Peak’s ability to execute on its growth strategy of acquiring additional mineral and royalty interests. Additionally, the steps taken by national, state and local governments to curb the spread of the COVID-19 pandemic, including stay-at-home orders, quarantines, travel restrictions and business shutdowns, and the implications on Desert Peak’s operators’ workforce of a COVID-19 infection, have limited Desert Peak’s operators’ ability to maintain production from Desert Peak’s properties. Such orders and the other impacts of the COVID-19 pandemic may have limited the ability of Desert Peak’s operators to access Desert Peak’s properties and maintain their existing production and development activities, and any similar or more restrictive measures taken in the future could have similar effects.

While Desert Peak’s business and operations have experienced certain effects of the COVID-19 pandemic as described above, the full extent of the impact of the COVID-19 pandemic on Desert Peak’s operational and financial performance, including Desert Peak’s ability to execute its business strategies and initiatives in the expected time frame, is uncertain and depends on various factors, including the demand for oil and natural gas (including the impact that reductions in travel, manufacturing and consumer product demand have had and will have on the demand for commodities), the availability of personnel, equipment and services critical to operating production activities by Desert Peak’s operators and the impact of potential governmental restrictions on travel, transportation and operations. The degree to which the COVID-19 pandemic or any other public health crisis adversely impacts Desert Peak’s operations, financial results and dividend policy will also depend on future developments, which are highly uncertain and cannot be predicted. These developments include, but are not limited to, the duration and spread of the pandemic, its severity, the actions to contain the virus or treat its impact, its impact on the economy and market conditions, and how quickly and to what extent normal economic and operating conditions can resume. While Desert Peak expects this matter will continue to disrupt its operations in some way, the degree of the adverse financial impact cannot be reasonably estimated at this time.

Desert Peak does not currently plan to enter into hedging arrangements with respect to the crude oil, natural gas and NGL production from its properties, and Desert Peak will be exposed to the impact of decreases in the price of crude oil, natural gas and NGLs.

Desert Peak does not currently plan to enter into hedging arrangements to establish, in advance, a price for the sale of the crude oil, natural gas and NGLs produced from its properties. As a result, although Desert Peak may realize the benefit of any short-term increase in the price of crude oil, natural gas and NGLs, Desert Peak will not be protected against decreases in the price of crude oil, natural gas and NGLs or prolonged periods of low commodity prices, which, in combination with its producing properties being located solely in the Delaware Basin, could materially adversely affect its business, results of operation and cash available for distribution. If Desert Peak enters into hedging arrangements in the future, it may limit Desert Peak’s ability to realize the benefit of rising prices and may result in hedging losses.

In the future, Desert Peak may enter into hedging transactions, which may not be effective in reducing the volatility of its cash flows.

In the future, Desert Peak may enter into hedging transactions with the intent of reducing volatility in its cash flows due to fluctuations in the price of crude oil, natural gas and NGLs. However, these hedging activities may not be as effective as Desert Peak intends in reducing the volatility of its cash flows and, if entered into, are subject to the risks that the terms of the derivative instruments will be imperfect, a counterparty may not perform its obligations under a derivative contract, there may be a change in the expected differential between the underlying commodity price in the derivative instrument and the actual price received, Desert Peak’s hedging policies and procedures may not be properly followed and the steps Desert Peak takes to monitor its derivative financial instruments may not detect and prevent violations of its risk management policies and procedures,

 

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particularly if deception or other intentional misconduct is involved. Further, Desert Peak may be limited in receiving the full benefit of increases in crude oil, natural gas and NGLs prices as a result of these hedging transactions. The occurrence of any of these risks could prevent Desert Peak from realizing the benefit of a derivative contract.

Desert Peak’s estimated reserves are based on many assumptions that may turn out to be inaccurate. Any material inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of its reserves.

It is not possible to measure underground accumulation of crude oil, natural gas or NGLs in an exact way. Crude oil, natural gas and NGL reserve engineering is not an exact science and requires subjective estimates of underground accumulations of crude oil, natural gas and NGLs and assumptions concerning future crude oil, natural gas and NGL prices, production levels, ultimate recoveries and operating and development costs. As a result, estimated quantities of proved reserves, projections of future production rates and the timing of development expenditures may turn out to be incorrect. Estimates of Desert Peak’s proved reserves and related valuations as of December 31, 2021 and 2020 were prepared by Cawley, Gillespie and Associates, Inc. (“CG&A”). CG&A conducted a detailed review of all of Desert Peak’s properties for the period covered by its reserve report using information provided by Desert Peak. Over time, Desert Peak may make material changes to reserve estimates taking into account the results of actual drilling, testing and production and changes in prices. In addition, certain assumptions regarding future crude oil, natural gas and NGL prices, production levels and operating and development costs may prove incorrect. For example, due to the deterioration in commodity prices and operator activity in 2020 as a result of the COVID-19 pandemic and other factors, the commodity price assumptions used to calculate Desert Peak’s reserves estimates declined, which in turn lowered its proved reserve estimates. A substantial portion of Desert Peak’s reserve estimates are made without the benefit of a lengthy production history, which are less reliable than estimates based on a lengthy production history. Any significant variance from these assumptions to actual figures could greatly affect Desert Peak’s estimates of reserves and future cash generated from operations. Numerous changes over time to the assumptions on which Desert Peak’s reserve estimates are based, as described above, often result in the actual quantities of crude oil, natural gas and NGLs that are ultimately recovered being different from its reserve estimates.

Furthermore, the present value of future net cash flows from Desert Peak’s proved reserves is not necessarily the same as the current market value of its estimated reserves. In accordance with rules established by the SEC and the Financial Accounting Standards Board (the “FASB”), Desert Peak bases the estimated discounted future net cash flows from its proved reserves on the twelve-month average oil and gas index prices, calculated as the unweighted arithmetic average for the first-day-of-the-month price for each month, and costs in effect on the date of the estimate, holding the prices and costs constant throughout the life of the properties. Actual future prices and costs may differ materially from those used in the present value estimate, and future net present value estimates using then current prices and costs may be significantly less than the current estimate. In addition, the 10% discount factor Desert Peak uses when calculating discounted future net cash flows may not be the most appropriate discount factor based on interest rates in effect from time to time and risks associated with Desert Peak or the crude oil and natural gas industry in general.

 

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Desert Peak relies on a small number of key individuals whose absence or loss could adversely affect its business.

Many key responsibilities within Desert Peak’s business have been assigned to a small number of individuals. Desert Peak relies on members of its executive management team for their knowledge of the crude oil and natural gas industry, relationships within the industry and experience in identifying, evaluating and completing acquisitions, especially in the Permian Basin. The loss of their services could adversely affect Desert Peak’s business. In particular, the loss of the services of one or more members of Desert Peak’s executive team could disrupt its business. Further, Desert Peak does not maintain “key person” life insurance policies on any of its executive team or other key personnel. As a result, Desert Peak is not insured against any losses resulting from the death of these key individuals.

Acreage must be drilled before lease expiration, generally within three to five years, in order to hold the acreage by production. Desert Peak’s E&P operators’ failure to drill sufficient wells to hold acreage may result in the deferral of prospective drilling opportunities. In addition, Desert Peak’s ORRIs may be lost if the underlying acreage is not drilled before the expiration of the applicable lease or if the lease otherwise terminates.

Leases on crude oil and natural gas properties typically have a term of three to five years, after which they expire unless, prior to expiration, production is established within the spacing units covering the undeveloped acres. In addition, even if production or drilling is established during such primary term, if production or drilling ceases on the leased property, the lease typically terminates, subject to certain exceptions.

Any reduction in Desert Peak’s E&P operators’ drilling programs, either through a reduction in capital expenditures or the unavailability of drilling rigs, could result in the expiration of existing leases. If the lease governing any of Desert Peak’s mineral interests expires or terminates, all mineral rights revert back to Desert Peak and Desert Peak will have to seek new lessees to explore and develop such mineral interests. If the lease underlying any of Desert Peak’s overriding royalty interests (“ORRIs”) expires or terminates, Desert Peak’s ORRIs that are derived from such lease will also terminate. Any such expirations or terminations of Desert Peak’s leases or its ORRIs could materially and adversely affect its financial condition, results of operations and cash flows.

If an owner of working interests burdened by Desert Peak’s ORRIs declares bankruptcy and a court determines that all or a portion of such ORRIs were part of the bankruptcy estate, Desert Peak could be treated as an unsecured creditor with respect to such ORRIs.

In determining whether ORRIs may be treated as part of a bankruptcy estate, a court may take into consideration a variety of factors including, among others, whether ORRIs are typically characterized as a real property interest under applicable state law, the terms conveying the ORRIs and related working interests and the applicable state law procedures required to perfect the interests such parties intend to create. Desert Peak believes that its ORRIs would be treated as an interest in real property in the states where they are located and, therefore, would not likely be considered a part of the bankruptcy estate. Nevertheless, the outcome is not certain. As such, if an owner of working interests burdened by Desert Peak’s ORRIs declares bankruptcy, a court may determine that all or a portion of such ORRIs are part of the bankruptcy estate. In that event, Desert Peak would be treated as a creditor in the bankruptcy case. Although holders of ORRIs may be entitled to statutory liens and/or other protections under applicable state law that could be enforceable in bankruptcy, there is no guarantee that such security interests or other protections would apply. Therefore, Desert Peak could be treated as an unsecured creditor of the debtor working interest holder and could lose the entire value of such ORRI.

 

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Operating hazards and uninsured risks may result in substantial losses to Desert Peak or its E&P operators, and any losses could adversely affect Desert Peak’s results of operations and cash flows.

The operations of Desert Peak’s E&P operators will be subject to all of the hazards and operating risks associated with drilling for and production of crude oil, natural gas and NGLs, including the risk of fire, explosions, blowouts, surface cratering, uncontrollable flows of crude oil, natural gas, NGLs and formation water, pipe or pipeline failures, abnormally pressured formations, casing collapses and environmental hazards such as crude oil and NGL spills, natural gas leaks and ruptures or discharges of toxic gases. In addition, their operations will be subject to risks associated with hydraulic fracturing, including any mishandling, surface spillage or potential underground migration of fracturing fluids, including chemical additives. The occurrence of any of these events could result in substantial losses to Desert Peak’s E&P operators due to injury or loss of life, severe damage to or destruction of property, natural resources and equipment, pollution or other environmental damage, clean-up responsibilities, regulatory investigations and penalties, suspension of operations and repairs required to resume operations.

Loss of Desert Peak’s or its E&P operators’ information and computer systems, including as a result of cyber attacks, could materially and adversely affect Desert Peak’s business.

Desert Peak and its E&P operators rely on electronic systems and networks to control and manage Desert Peak’s respective businesses. If any of such programs or systems were to fail for any reason, including as a result of a cyber attack, or create erroneous information in Desert Peak’s or its E&P operators’ hardware or software network infrastructure, possible consequences could be significant, including loss of communication links and inability to automatically process commercial transaction or engage in similar automated or computerized business activities. Although Desert Peak has multiple layers of security to mitigate risks of cyber attacks, cyber attacks on business have escalated in recent years. Moreover, Desert Peak’s E&P operators are becoming increasingly dependent on digital technologies to conduct certain exploration, development, production and processing activities, including interpreting seismic data, managing drilling rigs, production activities and gathering systems, conducting reservoir modeling and estimating reserves. The U.S. government has issued public warnings that indicate that energy assets might be specific targets of cyber security threats. If Desert Peak’s E&P operators become the target of cyber attacks of information security breaches, their business operations may be substantially disrupted, which could have an adverse effect on Desert Peak’s results of operations. In addition, Desert Peak’s and its E&P operators efforts to monitor, mitigate and manage these evolving risks may result in increased capital and operating costs, and there can be no assurance that such efforts will be sufficient to prevent attacks or breaches from occurring.

A terrorist attack or armed conflict could harm Desert Peak’s business.

Terrorist activities, anti-terrorist activities and other armed conflicts involving the United States or other countries may adversely affect the United States and global economies and could prevent Desert Peak from meeting its financial and other obligations. For example, on February 24, 2022, Russia launched a large-scale invasion of Ukraine that has led to significant armed hostilities. As a result, the United States, the United Kingdom, the member states of the European Union and other public and private actors have levied severe sanctions on Russia. The geopolitical and macroeconomic consequences of this invasion and associated sanctions cannot be predicted, and such events, or any further hostilities in Ukraine or elsewhere, could severely impact the world economy. If any of these events occur, the resulting political instability and societal disruption could reduce overall demand for crude oil, natural gas and NGLs, potentially putting downward pressure on demand for Desert Peak’s E&P operators’ services and causing a reduction in its revenues. Crude oil, natural gas and NGL related facilities, including those of Desert Peak’s operators, could be direct targets of terrorist attacks, and, if infrastructure integral to its E&P operators is destroyed or damaged, they may experience a significant disruption in their operations. Any such disruption could materially adversely affect Desert Peak’s financial condition, results of operations and cash flows. Costs for insurance and other security may increase as a result of these threats, and some insurance coverage may become more difficult to obtain, if available at all.

 

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Risks Related to Desert Peak’s Industry

A substantial majority of Desert Peak’s revenues from the crude oil and gas producing activities of its E&P operators are derived from royalty payments that are based on the price at which crude oil, natural gas and NGLs produced from the acreage underlying its interests are sold. Prices of crude oil, natural gas and NGLs are volatile due to factors beyond Desert Peak’s control. A substantial or extended decline in commodity prices may adversely affect Desert Peak’s business, financial condition, results of operations and cash flows.

Desert Peak’s revenues, operating results, discretionary cash flows and the carrying value of its mineral and royalty interests depend significantly upon the prevailing prices for crude oil, natural gas and NGLs. Historically, crude oil, natural gas and NGL prices and their applicable basis differentials have been volatile and are subject to fluctuations in response to changes in supply and demand, market uncertainty and a variety of additional factors that are beyond Desert Peak’s control, including:

 

   

the domestic and foreign supply of and demand for crude oil, natural gas and NGLs;

 

   

the level of prices and market expectations about future prices of crude oil, natural gas and NGLs;

 

   

the level of global crude oil, natural gas and NGL E&P;

 

   

the cost of exploring for, developing, producing and delivering crude oil, natural gas and NGLs;

 

   

the price and quantity of foreign imports and U.S. exports of crude oil, natural gas and NGLs;

 

   

the level of U.S. domestic production;

 

   

political and economic conditions and events in foreign oil, natural gas and NGL producing countries, including embargoes, continued hostilities in the Middle East and other sustained military campaigns, the armed conflict in Ukraine and associated economic sanctions on Russia, conditions in South America, Central America and China and acts of terrorism or sabotage;

 

   

global or national health concerns, including the outbreak of an illness pandemic (like COVID-19), which may reduce demand for crude oil, natural gas and NGLs due to reduced global or national economic activity;

 

   

the ability of members of OPEC and other oil exporting nations to agree to and maintain crude oil price and production controls;

 

   

speculative trading in crude oil, natural gas and NGL derivative contracts;

 

   

the level of consumer product demand;

 

   

weather conditions and other natural disasters, such as hurricanes and winter storms, the frequency and impact of which could be increased by the effects of climate change;

 

   

technological advances affecting energy consumption, energy storage and energy supply;

 

   

domestic and foreign governmental regulations and taxes;

 

   

the continued threat of terrorism and the impact of military and other action, including U.S. military operations in the Middle East and economic sanctions such as those imposed by the U.S. on oil and gas exports from Iran;

 

   

the proximity, cost, availability and capacity of crude oil, natural gas and NGL pipelines and other transportation facilities;

 

   

the price and availability of alternative fuels; and

 

   

overall domestic and global economic conditions.

These factors and the volatility of the energy markets make it extremely difficult to predict future crude oil, natural gas and NGL price movements with any certainty. For example, during the past five years, the posted

 

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price for West Texas Intermediate (“WTI”) light sweet crude oil has ranged from a historic, record low price of negative ($36.98) per barrel (“Bbl”) in April 2020 to a high of $123.64 per Bbl in March 2022, and the Henry Hub spot market price for natural gas has ranged from a low of $1.33 per metric million British thermal unit (“MMBtu”) in September 2020 to a high of $23.86 per MMBtu in February 2021. Certain actions by OPEC+ in the first half of 2020, combined with the impact of the continued outbreak of the COVID-19 pandemic and a shortage in available storage for hydrocarbons in the U.S., contributed to the historic low price for crude oil in April 2020. While the prices for crude oil have begun to stabilize and also increase, such prices have historically remained volatile, which has adversely affected the prices at which production from Desert Peak’s properties is sold as well as the production activities of operators on Desert Peak’s properties and may continue to do so in the future. This, in turn, has and will materially affect the amount of royalty payments that Desert Peak receives from such operators.

Any substantial decline in the price of crude oil, natural gas and NGLs or prolonged period of low commodity prices will materially adversely affect Desert Peak’s business, financial condition, results of operations and cash flows. In addition, lower crude oil, natural gas and NGL prices may reduce the amount of crude oil, natural gas and NGLs that can be produced economically by Desert Peak’s E&P operators, which may reduce its E&P operators’ willingness to develop its properties. This may result in Desert Peak having to make substantial downward adjustments to its estimated proved reserves, which could negatively impact the borrowing base under its revolving credit facility and its ability to fund its operations. If this occurs or if production estimates change or exploration or development results deteriorate, the successful efforts method of accounting principles may require Desert Peak to write down, as a non-cash charge to earnings, the carrying value of its crude oil and natural gas properties. Desert Peak’s E&P operators could also determine during periods of low commodity prices to shut in or curtail production from wells on Desert Peak’s properties. In addition, they could determine during periods of low commodity prices to plug and abandon marginal wells that otherwise may have been allowed to continue to produce for a longer period under conditions of higher prices. Specifically, they may abandon any well if they reasonably believe that the well can no longer produce crude oil, natural gas or NGLs in commercially paying quantities. Desert Peak may choose to use various derivative instruments in connection with anticipated crude oil, natural gas and NGL sales to minimize the impact of commodity price fluctuations. However, Desert Peak cannot hedge the entire exposure of its operations from commodity price volatility. To the extent Desert Peak does not hedge against commodity price volatility, or its hedges are not effective, Desert Peak’s results of operations and financial position may be diminished.

If commodity prices decrease to a level such that Desert Peak’s future undiscounted cash flows from its properties are less than their carrying value, Desert Peak may be required to take write-downs of the carrying values of its properties.

Accounting rules require that Desert Peak periodically review the carrying value of its properties for possible impairment. Based on specific market factors and circumstances at the time of prospective impairment reviews, production data, economics and other factors, Desert Peak may be required to write down the carrying value of its properties. Desert Peak evaluates the carrying amount of its proved oil, natural gas and NGL properties for impairment whenever events or changes in circumstances indicate that a property’s carrying amount may not be recoverable. If the carrying value exceeds the estimated undiscounted future cash flows Desert Peak would estimate the fair value of its properties and record an impairment charge for any excess of the carrying value of the properties over the estimated fair value of the properties. Factors used to estimate fair value may include estimates of proved reserves, future commodity prices, future production estimates and a commensurate discount rate. Because estimated undiscounted future cash flows have exceeded the carrying value of Desert Peak’s proved properties to date, it has not been necessary for Desert Peak to estimate the fair value of its properties under GAAP for successful efforts accounting. As a result, Desert Peak has not recorded any impairment expenses associated with its proved properties. While Desert Peak did not record any impairment during the year ended December 31, 2021, for the year ended December 31, 2020, Desert Peak recorded an impairment charge of $812,000 in connection with capitalized acquisition costs for a prospective mineral interest acquisition that it did not complete. The risk that Desert Peak will be required to recognize impairments of its

 

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crude oil, natural gas and NGL properties increases during periods of low commodity prices. In addition, impairments would occur if Desert Peak were to experience sufficient downward adjustments to its estimated proved reserves or the present value of estimated future net revenues. An impairment recognized in one period may not be reversed in a subsequent period. Desert Peak may incur impairment charges in the future, which could materially adversely affect its results of operations for the periods in which such charges are taken.

The unavailability, high cost or shortages of rigs, equipment, raw materials, supplies or personnel may restrict or result in increased costs for E&P operators related to developing and operating Desert Peak’s properties.

The crude oil and natural gas industry is cyclical, which can result in shortages of drilling rigs, equipment, raw materials (particularly water and sand and other proppants), supplies and personnel. When shortages occur, the costs and delivery times of rigs, equipment and supplies increase and demand for, and wage rates of, qualified drilling rig crews also rise with increases in demand. Desert Peak cannot predict whether these conditions will exist in the future and, if so, what their timing and duration will be. In accordance with customary industry practice, Desert Peak’s E&P operators rely on independent third-party service providers to provide many of the services and equipment necessary to drill new wells. If Desert Peak’s E&P operators are unable to secure a sufficient number of drilling rigs at reasonable costs, Desert Peak’s financial condition and results of operations could suffer. Shortages of drilling rigs, equipment, raw materials, supplies, personnel, trucking services, tubulars, hydraulic fracturing and completion services and production equipment could delay or restrict Desert Peak’s E&P operators’ exploration and development operations, which in turn could have a material adverse effect on Desert Peak’s financial condition, results of operations and cash flows.

The marketability of crude oil, natural gas and NGL production is dependent upon transportation and processing and refining facilities, which neither Desert Peak nor many of its E&P operators control. Any limitation in the availability of those facilities could interfere with Desert Peak’s or its E&P operators’ ability to market Desert Peak’s or its E&P operators’ production and could harm Desert Peak’s business.

The marketability of Desert Peak’s or its E&P operators’ production depends in part on the availability, proximity and capacity of pipelines, tanker trucks and other transportation methods, and processing and refining facilities owned by third parties. Neither Desert Peak nor its E&P operators control these third-party facilities and Desert Peak’s E&P operators’ access to them may be limited or denied. Insufficient production from the wells on Desert Peak’s acreage or a significant disruption in the availability of third-party transportation facilities or other production facilities could adversely impact Desert Peak’s E&P operators’ ability to deliver, to market or produce oil and natural gas and thereby cause a significant interruption in Desert Peak’s operators’ operations. If they are unable, for any sustained period, to implement acceptable delivery or transportation arrangements or encounter production related difficulties, they may be required to shut in or curtail production. In addition, the amount of crude oil that can be produced and sold is subject to curtailment in certain other circumstances outside of Desert Peak’s or its operators’ control, such as pipeline interruptions due to scheduled and unscheduled maintenance, excessive pressure, physical damage or lack of available capacity on these systems, tanker truck availability and extreme weather conditions. Also, production from Desert Peak’s wells may be insufficient to support the construction of pipeline facilities, and the shipment of Desert Peak’s or its E&P operators’ crude oil, natural gas and NGLs on third-party pipelines may be curtailed or delayed if it does not meet the quality specifications of the pipeline owners. The curtailments arising from these and similar circumstances may last from a few days to several months. In many cases, Desert Peak and its E&P operators are provided only with limited, if any, notice as to when these circumstances will arise and their duration. Any significant curtailment in gathering system or transportation, processing or refining-facility capacity, or an inability to obtain favorable terms for delivery of the crude oil and natural gas produced from Desert Peak’s acreage, could reduce Desert Peak’s or its E&P operators’ ability to market the production from Desert Peak’s properties and have a material adverse effect on Desert Peak’s financial condition, results of operations and cash flows. Desert Peak’s or its E&P operators’ access to transportation options and the prices Desert Peak or its E&P operators receive can also be affected by federal and state regulation—including regulation of crude oil, natural gas and NGL production, transportation and pipeline safety—as well by general economic conditions and changes in supply and demand.

 

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In addition, the third parties on whom Desert Peak or its E&P operators rely for transportation services are subject to complex federal, state, tribal and local laws that could adversely affect the cost, manner or feasibility of conducting Desert Peak’s business.

Drilling for and producing crude oil, natural gas and NGLs are high-risk activities with many uncertainties that may materially adversely affect Desert Peak’s business, financial condition, results of operations and cash flows.

The drilling activities of the E&P operators of Desert Peak’s properties will be subject to many risks. For example, Desert Peak will not be able to assure you that wells drilled by the E&P operators of its properties will be productive. Drilling for crude oil, natural gas and NGLs often involves unprofitable efforts, not only from dry wells but also from wells that are productive but do not produce sufficient crude oil, natural gas or NGLs to return a profit at then realized prices after deducting drilling, operating and other costs. The seismic data and other technologies used do not provide conclusive knowledge prior to drilling a well that crude oil, natural gas or NGLs are present or that a well can be produced economically. The costs of exploration, exploitation and development activities are subject to numerous uncertainties beyond Desert Peak’s control and increases in those costs can adversely affect the economics of a project. Further, Desert Peak’s E&P operators’ drilling and producing operations may be curtailed, delayed, canceled or otherwise negatively impacted as a result of other factors, including:

 

   

unusual or unexpected geological formations;

 

   

loss of drilling fluid circulation;

 

   

title problems;

 

   

facility or equipment malfunctions;

 

   

unexpected operational events;

 

   

shortages or delivery delays of equipment and services;

 

   

compliance with environmental and other governmental requirements; and

 

   

adverse weather conditions, including the recent winter storms in February 2021 that adversely affected operator activity and production volumes in the southern United States, including in the Delaware Basin.

Any of these risks can cause substantial losses, including personal injury or loss of life, damage to or destruction of property, natural resources and equipment, pollution, environmental contamination or loss of wells and other regulatory penalties. In the event that planned operations, including the drilling of development wells, are delayed or cancelled, or existing wells or development wells have lower than anticipated production due to one or more of the factors above or for any other reason, Desert Peak’s financial condition, results of operations and cash flows may be materially adversely affected.

Competition in the crude oil and natural gas industry is intense, which may adversely affect Desert Peak’s and its E&P operators’ ability to succeed.

The crude oil and natural gas industry is intensely competitive, and the E&P operators of Desert Peak’s properties compete with other companies that may have greater resources. Many of these companies explore for and produce crude oil, natural gas and NGLs, carry on midstream and refining operations, and market petroleum and other products on a regional, national or worldwide basis. In addition, these companies may have a greater ability to continue exploration activities during periods of low crude oil, natural gas and NGL market prices. Desert Peak’s E&P operators’ larger competitors may be able to absorb the burden of present and future federal, state, local and other laws and regulations more easily than Desert Peak’s E&P operators can, which would adversely affect Desert Peak’s E&P operators’ competitive position. Desert Peak’s E&P operators may have

 

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fewer financial and human resources than many companies in Desert Peak’s E&P operators’ industry and may be at a disadvantage in bidding for exploratory prospects and producing crude oil and natural gas properties. Furthermore, the crude oil and natural gas industry has experienced recent consolidation among some operators, which has resulted in certain instances of combined companies with larger resources. Such combined companies may compete against Desert Peak’s E&P operators or, in the case of consolidation among Desert Peak’s E&P operators, may choose to focus their operations on areas outside of Desert Peak’s properties. In addition, Desert Peak’s ability to acquire additional properties and to discover reserves in the future will be dependent upon its ability to evaluate and select suitable properties and to consummate transaction in a highly competitive environment.

A deterioration in general economic, business, political or industry conditions would materially adversely affect Desert Peak’s results of operations, financial condition and cash flows.

Concerns over global economic conditions, energy costs, geopolitical issues, the impacts of the COVID-19 pandemic, inflation, the availability and cost of credit and slow economic growth in the United States have contributed to economic uncertainty and diminished expectations for the global economy. Additionally, acts of protest and civil unrest have caused economic and political disruption in the United States. Meanwhile, continued hostilities in the Middle East and the occurrence or threat of terrorist attacks in the United States or other countries could adversely affect the economies of the United States and other countries. Concerns about global economic growth have had a significant adverse impact on global financial markets and commodity prices. An oversupply of crude oil in 2020 led to a severe decline in worldwide crude oil prices in 2020. If the economic climate in the United States or abroad deteriorates, worldwide demand for petroleum products could further diminish, which could impact the price at which crude oil, natural gas and NGLs from Desert Peak’s properties are sold, affect the ability of Desert Peak’s E&P operators to continue operations and ultimately materially adversely impact Desert Peak’s results of operations, financial condition and cash flows.

Conservation measures, technological advances and increasing attention to ESG matters could materially reduce demand for crude oil, natural gas and NGLs, availability of capital and adversely affect Desert Peak’s results of operations.

Fuel conservation measures, alternative fuel requirements, increasing consumer demand for alternatives to crude oil, natural gas and NGLs, technological advances in fuel economy and energy-generation devices could reduce demand for crude oil, natural gas and NGLs. The impact of the changing demand for crude oil, natural gas and NGL services and products may have a material adverse effect on Desert Peak’s business, financial condition, results of operations and cash flows. It is also possible that the concerns about the production and use of fossil fuels will reduce the sources of financing available to Desert Peak. For example, certain segments of the investor community have developed negative sentiment towards investing in the oil and gas industry. Recent equity returns in the sector versus other industry sectors have led to lower oil and gas representation in certain key equity market indices. In addition, some investors, including investment advisors and certain sovereign wealth, pension funds, university endowments and family foundations, have stated policies to divest from, or not provide funding to, the oil and gas sector based on their social and environmental considerations. Furthermore, organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to environmental, social and governance (“ESG”) matters. Such ratings are used by some investors and other financial institutions to inform their investment, financing and voting decisions, and unfavorable ESG ratings may lead to increased negative sentiment toward oil and gas companies from such institutions. Certain other stakeholders have also pressured commercial and investment banks to stop financing oil and gas and related infrastructure projects. Such developments, including environmental activism and initiatives aimed at limiting climate change and reducing air pollution, could result in downward pressure on the stock prices of oil and gas companies, and also adversely affect Desert Peak’s availability of capital.

 

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Risks Related to Environmental and Regulatory Matters

Crude oil, natural gas and NGL operations are subject to various governmental laws and regulations. Compliance with these laws and regulations can be burdensome and expensive for Desert Peak’s E&P operators, and failure to comply could result in its E&P operators incurring significant liabilities, either of which may impact its E&P operators’ willingness to develop Desert Peak’s interests.

Desert Peak’s E&P operators’ activities on the properties in which Desert Peak holds interests are subject to various federal, state and local governmental regulations that may change from time to time in response to economic and political conditions. Matters subject to regulation include drilling operations, production and distribution activities, discharges or releases of pollutants or wastes, plugging and abandonment of wells, maintenance and decommissioning of other facilities, the spacing of wells, unitization and pooling of properties and taxation. From time to time, regulatory agencies have imposed price controls and limitations on production by restricting the rate of flow of crude oil and natural gas wells below actual production capacity to conserve supplies of crude oil, natural gas and NGLs. For example, in January 2021, President Biden signed an Executive Order that, among other things, instructed the Secretary of the Interior to pause new oil and natural gas leases on public lands or in offshore waters pending completion of a comprehensive review and reconsideration of federal oil and natural gas permitting and leasing practices; however, in June 2021, a federal judge for the U.S. District Court of the Western District of Louisiana issued a nationwide preliminary injunction against the pause of new oil and natural gas leases while litigation challenging the Executive Order and its implementation is ongoing. In November 2021, the Department of the Interior issued a report recommending various changes to the federal leasing program, though many such changes would require Congressional action. Substantially all of Desert Peak’s interests are located on private lands, but Desert Peak cannot predict the full impact of these developments or whether the Biden Administration may pursue further restrictions. President Biden also issued an Executive Order directing all federal agencies to review and take action to address any federal regulations, orders, guidance documents, policies and any similar agency actions during the prior administration that may be inconsistent with the current administration’s policies. Further actions of President Biden, and the Biden Administration, including actions focused on addressing climate change, may negatively impact oil and gas operations and favor renewable energy projects in the United States, which may negatively impact the demand for oil and natural gas.

In addition, the production, handling, storage and transportation of crude oil, natural gas and NGLs, as well as the remediation, emission and disposal of crude oil, natural gas and NGL wastes, by-products thereof and other substances and materials produced or used in connection with crude oil, natural gas and NGL operations are subject to regulation under federal, state and local laws and regulations primarily relating to protection of worker health and safety, natural resources and the environment. Failure to comply with these laws and regulations may result in the assessment of sanctions on Desert Peak’s E&P operators, including administrative, civil or criminal penalties, permit revocations, requirements for additional pollution controls and injunctions limiting or prohibiting some or all of Desert Peak’s E&P operators’ operations on Desert Peak’s properties. Moreover, these laws and regulations have generally imposed increasingly strict requirements related to water use and disposal, air pollution control, species protection, and waste management, among other matters.

Laws and regulations governing E&P may also affect production levels. Desert Peak’s E&P operators must comply with federal and state laws and regulations governing conservation matters, including, but not limited to:

 

   

provisions related to the unitization or pooling of the crude oil and natural gas properties;

 

   

the establishment of maximum rates of production from wells;

 

   

the spacing of wells;

 

   

the plugging and abandonment of wells; and

 

   

the removal of related production equipment.

Additionally, federal and state regulatory authorities may expand or alter applicable pipeline-safety laws and regulations, compliance with which may require increased capital costs for third-party crude oil, natural gas and

 

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NGL transporters. These transporters may attempt to pass on such costs to Desert Peak’s E&P operators, which in turn could affect profitability on the properties in which Desert Peak owns mineral and royalty interests.

Desert Peak’s E&P operators must also comply with laws and regulations prohibiting fraud and market manipulations in energy markets. To the extent the E&P operators of Desert Peak’s properties are shippers on interstate pipelines, they must comply with the tariffs of those pipelines and with federal policies related to the use of interstate capacity.

Desert Peak’s E&P operators may be required to make significant expenditures to comply with the governmental laws and regulations described above and may be subject to potential fines and penalties if they are found to have violated these laws and regulations. Desert Peak believes the trend of more expansive and stricter environmental legislation and regulations will continue. Please read “Information About Desert Peak—Business—Regulation” for a description of the laws and regulations that affect Desert Peak’s E&P operators and that may affect Desert Peak. These and other potential regulations could increase the operating costs of Desert Peak’s E&P operators and delay production and may ultimately impact Desert Peak’s E&P operators’ ability and willingness to develop Desert Peak’s properties.

Federal and state legislative and regulatory initiatives relating to hydraulic fracturing could cause Desert Peak’s E&P operators to incur increased costs, additional operating restrictions or delays and have fewer potential drilling locations.

Desert Peak’s E&P operators engage in hydraulic fracturing. Hydraulic fracturing is a common practice that is used to stimulate production of hydrocarbons from tight formations, including shales. The process involves the injection of water, sand and chemicals under pressure into formations to fracture the surrounding rock and stimulate production. Currently, hydraulic fracturing is generally exempt from regulation under the Underground Injection Control program of the U.S. Safe Drinking Water Act (“SDWA”) and is typically regulated by state oil and gas commissions or similar agencies.

However, several federal agencies have asserted regulatory authority over certain aspects of the process. For example, in June 2016, the Environmental Protection Agency (the “EPA”) published an effluent limit guideline final rule prohibiting the discharge of wastewater from onshore unconventional oil and gas extraction facilities to publicly owned wastewater treatment plants. Also, from time to time, legislation has been introduced, but not enacted, in the U.S. Congress to provide for federal regulation of hydraulic fracturing and to require disclosure of the chemicals used in the hydraulic fracturing process. This or other federal legislation related to hydraulic fracturing may be considered again in the future, though Desert Peak cannot predict the extent of any such legislation at this time.

Moreover, some states and local governments have adopted, and other governmental entities are considering adopting, regulations that could impose more stringent permitting, disclosure and well-construction requirements on hydraulic fracturing operations, including states in which Desert Peak’s properties are located. For example, Texas, among others, has adopted regulations that impose new or more stringent permitting, disclosure, disposal and well construction requirements on hydraulic fracturing operations. States could also elect to prohibit high volume hydraulic fracturing altogether. In addition to state laws, local land use restrictions, such as city ordinances, may restrict drilling in general and/or hydraulic fracturing in particular.

Increased regulation and attention given to the hydraulic fracturing process, including the disposal of produced water gathered from drilling and production activities, could lead to greater opposition to, and litigation concerning, crude oil, natural gas and NGL production activities using hydraulic fracturing techniques in areas where Desert Peak owns mineral and royalty interests. Additional legislation or regulation could also lead to operational delays or increased operating costs for Desert Peak’s E&P operators in the production of crude oil, natural gas and NGLs, including from the development of shale plays, or could make it more difficult for Desert Peak’s E&P operators to perform hydraulic fracturing. The adoption of any federal, state or local laws or the

 

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implementation of regulations regarding hydraulic fracturing could potentially cause a decrease in Desert Peak’s E&P operators’ completion of new crude oil and natural gas wells on Desert Peak’s properties and an associated decrease in the production attributable to Desert Peak’s interests, which could have a material adverse effect on Desert Peak’s business, financial condition and results of operations.

Legislation or regulatory initiatives intended to address seismic activity could restrict Desert Peak’s E&P operators’ drilling and production activities, as well as Desert Peak’s operators’ ability to dispose of produced water gathered from such activities, which could have a material adverse effect on their future business, which in turn could have a material adverse effect on Desert Peak’s business.

State and federal regulatory agencies have recently focused on a possible connection between hydraulic fracturing related activities, particularly the underground injection of wastewater into disposal wells, and the increased occurrence of seismic activity, and regulatory agencies at all levels are continuing to study the possible linkage between oil and gas activity and induced seismicity. For example, in 2015, the United States Geological Study (“USGS”) identified eight states, including New Mexico, Oklahoma and Texas, with areas of increased rates of induced seismicity that could be attributed to fluid injection or oil and gas extraction.

In addition, a number of lawsuits have been filed alleging that disposal well operations have caused damage to neighboring properties or otherwise violated state and federal rules regulating waste disposal. In response to these concerns, regulators in some states are seeking to impose additional requirements, including requirements in the permitting of produced water disposal wells or otherwise to assess the relationship between seismicity and the use of such wells. For example, the Texas Railroad Commission has previously published a rule governing permitting or re-permitting of disposal wells that would require, among other things, the submission of information on seismic events occurring within a specified radius of the disposal well location, as well as logs, geologic cross sections and structure maps relating to the disposal area in question. If the permittee or an applicant of a disposal well permit fails to demonstrate that the produced water or other fluids are confined to the disposal zone or if scientific data indicates such a disposal well is likely to be or determined to be contributing to seismic activity, then the agency may deny, modify, suspend or terminate the permit application or existing operating permit for that well. The Texas Railroad Commission has used this authority to deny permits for waste disposal wells. In some instances, regulators may also order that disposal wells be shut in. In late 2021, the Texas Railroad Commission issued a notice to operators of disposal wells in the Midland area to reduce saltwater disposal well actions and provide certain data to the commission. Separately, in November 2021, New Mexico implemented protocols requiring operators to take various actions within a specified proximity of certain seismic activity, including a requirement to limit injection rates if a seismic event is of a certain magnitude. As a result of these developments, Desert Peak’s operators may be required to curtail operations or adjust development plans, which may adversely impact Desert Peak’s business.

Desert Peak’s operators will likely dispose of large volumes of produced water gathered from their drilling and production operations by injecting it into wells pursuant to permits issued by governmental authorities overseeing such disposal activities. While these permits will be issued pursuant to existing laws and regulations, these legal requirements are subject to change, which could result in the imposition of more stringent operating constraints or new monitoring and reporting requirements, owing to, among other things, concerns of the public or governmental authorities regarding such gathering or disposal activities. The adoption and implementation of any new laws or regulations that restrict Desert Peak’s E&P operators’ ability to use hydraulic fracturing or dispose of produced water gathered from drilling and production activities by limiting volumes, disposal rates, disposal well locations or otherwise, or requiring them to shut down disposal wells, could have a material adverse effect on Desert Peak’s business, financial condition and results of operations.

 

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As a result of judicial interpretation of the Relinquishment Act, certain of Desert Peak’s surface rights entitle it to receive a fixed, lease operating expense and capital cost-free percentage of any oil and natural gas produced from reserves underlying the property. If the Relinquishment Act were to be amended or repealed or Desert Peak was subject to an unfavorable ruling under the Relinquishment Act, Desert Peak may no longer be able to derive additional rights to production from its ownership of surface rights, which may have a material adverse effect on its results of operations and cash flows.

Under the Relinquishment Act of 1919, as amended (the “Relinquishment Act”), the State of Texas owns mineral rights in certain lands. As a result of judicial interpretation of the Relinquishment Act, the surface owner of such lands may act as an agent for the state in negotiating and executing mineral leases, and, if the state approves the lease terms, the applicable surface owner receives an interest in the resulting royalty interest. Approximately 9% of Desert Peak’s net royalty acres (“NRAs”) as of December 31, 2021 were from the rights it received in this manner. However, if the Relinquishment Act were to be amended or repealed or if Desert Peak were subject to an unfavorable ruling under the Relinquishment Act, Desert Peak may no longer be able to derive revenue from the corresponding mineral rights, which may have a material adverse effect on its results of operations and cash flows.

Restrictions on the ability of Desert Peak’s E&P operators to obtain water may have an adverse effect on Desert Peak’s financial condition, results of operations and cash flows.

Water is an essential component of crude oil, natural gas and NGL production during both the drilling and hydraulic fracturing processes. Over the past several years, parts of the country, and in particular Texas, have experienced extreme drought conditions. As a result of this severe drought, some local water districts have begun restricting the use of water subject to their jurisdiction for hydraulic fracturing to protect local water supply. Such conditions may be exacerbated by climate change. If Desert Peak’s E&P operators are unable to obtain water to use in their operations from local sources, or if Desert Peak’s E&P operators are unable to effectively utilize flowback water, they may be unable to economically drill for or produce crude oil, natural gas and NGLs from Desert Peak’s properties, which could have an adverse effect on Desert Peak’s financial condition, results of operations and cash flows.

Desert Peak’s operations, and those of its E&P operators, are subject to a series of risks arising from climate change.

Climate change continues to attract considerable public and scientific attention. As a result, numerous proposals have been made and are likely to continue to be made at the international, national, regional and state levels of government to monitor and limit emissions of carbon dioxide, methane and other “greenhouse gases” (“GHGs”). These efforts have included consideration of cap-and-trade programs, carbon taxes, GHG reporting and tracking programs and regulations that directly limit GHG emissions from certain sources.

In the United States, no comprehensive climate change legislation has been implemented at the federal level. However, President Biden has highlighted addressing climate change as a priority of his administration and has issued several Executive Orders addressing climate change. Moreover, following the U.S. Supreme Court finding that GHG emissions constitute a pollutant under the Clean Air Act (the “CAA”), the EPA has adopted regulations that, among other things, establish construction and operating permit reviews for GHG emissions from certain large stationary sources, require the monitoring and annual reporting of GHG emissions from certain petroleum and natural gas system sources in the United States, and together with the U.S. Department of Transportation (the “DOT”), implementing GHG emissions limits on vehicles manufactured for operation in the United States. The regulation of methane from oil and gas facilities has been subject to uncertainty in recent years. In September 2020, the Trump Administration revised prior regulations to rescind certain methane standards and remove the transmission and storage segments from the source category for certain regulations. However, subsequently, the U.S. Congress approved, and President Biden signed into law, a resolution under the Congressional Review Act to repeal the September 2020 revisions to the methane standards, effectively

 

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reinstating the prior standards. Additionally, in November 2021, the EPA issued a proposed rule that, if finalized, would establish OOOO(b) new source and OOOO(c) first-time existing source standards of performance for methane and volatile organic compound emissions for oil and gas facilities. Operators of affected facilities will have to comply with specific standards of performance to include leak detection using optical gas imaging and subsequent repair requirement, and reduction of emissions by 95% through capture and control systems. The EPA plans to issue a supplemental proposal in 2022 containing additional requirements not included in the November 2021 proposed rule and anticipates the issuance of a final rule by the end of the year. We cannot predict the scope of any final methane regulatory requirements or the cost to comply with such requirements. However, given the long-term trend toward increasing regulation, future federal GHG regulations of the oil and gas industry remain a significant possibility.

Separately, various states and groups of states have adopted or are considering adopting legislation, regulation or other regulatory initiatives that are focused on such areas as GHG cap and trade programs, carbon taxes, reporting and tracking programs, and restriction of emissions. For example, New Mexico has adopted regulations to restrict the venting or flaring of methane from both upstream and midstream operations. At the international level, the United Nations-sponsored “Paris Agreement” requires member states to submit non-binding, individually-determined reduction goals known as Nationally Determined Contributions every five years after 2020. President Biden has recommitted the United States to the Paris Agreement and, in April 2021, announced a goal of reducing the United States’ emissions by 50-52% below 2005 levels by 2030. Additionally, at the 26th Conference of the Parties to the United Nations Framework Convention on Climate Change (“COP26”) in Glasgow in November 2021, the United States and the European Union jointly announced the launch of a Global Methane Pledge, an initiative committing to a collective goal of reducing global methane emissions by at least 30% from 2020 levels by 2030, including “all feasible reductions” in the energy sector. The full impact of these actions cannot be predicted at this time.

Governmental, scientific, and public concern over the threat of climate change arising from GHG emissions has resulted in increasing political risks in the United States, including climate change related pledges made by certain candidates now in public office. On January 27, 2021, President Biden issued an Executive Order that calls for substantial action on climate change, including, among other things, the increased use of zero-emission vehicles by the federal government, the elimination of subsidies provided to the fossil fuel industry, and increased emphasis on climate-related risks across government agencies and economic sectors. The Biden Administration has also called for restrictions on leasing on federal land, including the Department of the Interior’s publication of a report recommending various changes to the federal leasing program, though many such changes would require Congressional action. Substantially all of Desert Peak’s interests are located on private lands, but Desert Peak cannot predict the full impact of these developments or whether the Biden Administration may pursue further restrictions. Other actions that could be pursued by the Biden Administration may include the imposition of more restrictive requirements for the establishment of pipeline infrastructure or the permitting of liquefied natural gas (“LNG”) export facilities, as well as more restrictive GHG emission limitations for oil and gas facilities. Litigation risks are also increasing as a number of entities have sought to bring suit against various oil and natural gas companies in state or federal court, alleging among other things, that such companies created public nuisances by producing fuels that contributed to climate change or alleging that the companies have been aware of the adverse effects of climate change for some time but defrauded their investors or customers by failing to adequately disclose those impacts.

There are also increasing financial risks for fossil fuel producers as shareholders currently invested in fossil-fuel energy companies may elect in the future to shift some or all of their investments into non-fossil fuel related sectors. Institutional lenders who provide financing to fossil fuel energy companies also have become more attentive to sustainable lending practices and some of them may elect not to provide funding for fossil fuel energy companies. For example, at COP26, the Glasgow Financial Alliance for Net Zero (“GFANZ”) announced that commitments from over 450 firms across 45 countries had resulted in over $130 trillion in capital committed to net zero goals. The various sub-alliances of GFANZ generally require participants to set short-term, sector-specific targets to transition their financing, investing, and/or underwriting activities to net zero emissions by

 

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2050. There is also a risk that financial institutions will be required to adopt policies that have the effect of reducing the funding provided to the fossil fuel sector. In late 2020, the Federal Reserve announced that is has joined the Network for Greening the Financial System, a consortium of financial regulators focused on addressing climate-related risks in the financial sector. Subsequently, in November 2021, the Federal Reserve issued a statement in support of the efforts of the Network for Greening the Financial System to identify key issues and potential solutions for the climate-related challenges most relevant to central banks and supervisory authorities. Limitation of investments in and financing for fossil fuel energy companies could result in the restriction, delay or cancellation of drilling programs or development or production activities. Additionally, the SEC announced its intention to promulgate rules requiring climate disclosures. Although the form and substance of these requirements is not yet known, this may result in additional cots to comply with any such disclosure requirements.

The adoption and implementation of new or more stringent international, federal or state legislation, regulations or other regulatory initiatives that impose more stringent standards for GHG emissions from the oil and natural gas sector or otherwise restrict the areas in which this sector may produce oil and natural gas or generate the GHG emissions could result in increased costs of compliance or costs of consuming, and thereby reduce demand for oil and natural gas, which could reduce the profitability of Desert Peak’s interests. Additionally, political, litigation and financial risks may result in Desert Peak’s oil and natural gas operators restricting or cancelling production activities, incurring liability for infrastructure damages as a result of climatic changes, or impairing their ability to continue to operate in an economic manner, which also could reduce the profitability of its interests. One or more of these developments could have a material adverse effect on Desert Peak’s business, financial condition and results of operation.

Climate change may also result in various physical risks, such as the increased frequency or intensity of extreme weather events or changes in meteorological and hydrological patterns, that could adversely impact our operations, as well as those of our operators and their supply chains. Such physical risks may result in damage to operators’ facilities or otherwise adversely impact their operations, such as if they become subject to water use curtailments in response to drought, or demand for their products, such as to the extent warmer winters reduce the demand for energy for heating purposes.

Increased attention to ESG matters and conservation measures may adversely impact Desert Peak’s business or the business of its operators.

Increasing attention to climate change, societal expectations on companies to address climate change, investor and societal expectations regarding voluntary ESG disclosures, and consumer demand for alternative forms of energy may result in increased costs, reduced demand for Desert Peak’s operators’ products (and thus in Desert Peak’s mineral interests), reduced profits, and increased investigations and litigation. Increasing attention to climate change and environmental conservation, for example, may result in demand shifts for oil and natural gas products and additional governmental investigations and private litigation against Desert Peak or its operators. To the extent that societal pressures or political or other factors are involved, it is possible that such liability could be imposed without regard to Desert Peak’s causation of, or contribution to, the asserted damage, or to other mitigating factors.

Moreover, while Desert Peak may create and publish voluntary disclosures regarding ESG matters from time to time, many of the statements in those voluntary disclosures are based on hypothetical expectations and assumptions that may or may not be representative of current or actual risks or events or forecasts of expected risks or events, including the costs associated therewith. Such expectations and assumptions are necessarily uncertain and may be prone to error or subject to misinterpretation given the long timelines involved and the lack of an established single approach to identifying, measuring and reporting on many ESG matters.

In addition, organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to ESG matters. Such ratings are

 

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used by some investors to inform their investment and voting decisions. Unfavorable ESG ratings and recent activism directed at shifting funding away from companies with energy-related assets could lead to increased negative investor sentiment toward Desert Peak and its industry and to the diversion of investment to other industries, which could have a negative impact on Desert Peak’s or operators’ access to and costs of capital. Also, institutional lenders may decide not to provide funding for fossil fuel energy companies based on climate change related concerns, which could affect Desert Peak’s or its operators’ access to capital for potential growth projects.

Desert Peak’s or its E&P operators’ results of operations may be materially impacted by efforts to transition to a lower-carbon economy.

Concerns over the risk of climate change have increased the focus by global, regional, national, state and local regulators on GHG emissions, including carbon dioxide emissions, and on transitioning to a lower-carbon future. A number of countries and states have adopted, or are considering the adoption of, regulatory frameworks to reduce greenhouse gas emissions. These regulatory measures may include, among others, adoption of cap and trade regimes, carbon taxes, increased efficiency standards, prohibitions on the sales of new automobiles with internal combustion engines, and incentives or mandates for battery-powered automobiles and/or wind, solar or other forms of alternative energy. Compliance with changes in laws, regulations and obligations relating to climate change could result in increased costs of compliance for Desert Peak’s E&P operators or costs of consuming crude oil, natural gas and NGLs for such products, and thereby reduce demand, which could reduce the profitability of Desert Peak’s interests. For example, Desert Peak’s E&P operators may be required to install new emission controls, acquire allowances or pay taxes related to their greenhouse gas emissions, or otherwise incur costs to administer and manage a GHG emissions program. Additionally, Desert Peak or its operators could incur reputational risk tied to changing customer or community perceptions of its, its E&P operators’ or its E&P operators’ customers contribution to, or detraction from, the transition to a lower-carbon economy. These changing perceptions could lower demand for oil and gas products, resulting in lower prices and lower revenues as consumers avoid carbon-intensive industries, and could also pressure banks and investment managers to shift investments and reduce lending.

Separately, banks and other financial institutions, including investors, may decide to adopt policies that restrict or prohibit investment in, or otherwise funding, Desert Peak or its operators based on climate change-related concerns, which could affect its or its E&P operators’ access to capital for potential growth projects.

Approaches to climate change and transition to a lower-carbon economy, including government regulation, company policies, and consumer behavior, are continuously evolving. At this time, Desert Peak cannot predict how such approaches may develop or otherwise reasonably or reliably estimate their impact on its or its operators’ financial condition, results of operations and ability to compete. However, any long-term material adverse effect on the oil and gas industry may adversely affect Desert Peak’s financial condition, results of operations and cash flows.

Additional restrictions on drilling activities intended to protect certain species of wildlife may adversely affect Desert Peak’s E&P operators’ ability to conduct drilling activities.

In the United States, the Endangered Species Act (the “ESA”) restricts activities that may affect endangered or threatened species or their habitats. Similar protections are offered to migratory birds under the Migratory Bird Treaty Act (the “MBTA”). To the extent species that are listed under the ESA or similar state laws, or are protected under the MBTA, live in the areas where Desert Peak’s E&P operators operate, Desert Peak’s E&P operators’ abilities to conduct or expand operations could be limited, or Desert Peak’s E&P operators could be forced to incur material additional costs. Moreover, Desert Peak’s E&P operators’ drilling activities may be delayed, restricted or precluded in protected habitat areas or during certain seasons, such as breeding and nesting seasons. For example, in June 2021, the U.S. Fish & Wildlife Service (the “FWS”) proposed to list two distinct population sections of the Lesser Prairie Chicken, including one in portions of the Permian Basin, under the ESA.

 

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Recently, there have also been renewed calls to review protections currently in place for the dunes sagebrush lizard, whose habitat includes parts of the Permian Basin, and to reconsider listing the species under the ESA.

In addition, as a result of one or more settlements approved by the FWS, the agency was required to make a determination on the listing of numerous other species as endangered or threatened under the ESA by the end of the FWS’ 2017 fiscal year. The FWS did not meet that deadline, but continues to evaluate whether to take action with respect to those species. The designation of previously unidentified endangered or threatened species could cause Desert Peak’s E&P operators’ operations to become subject to operating restrictions or bans, and limit future development activity in affected areas. The FWS and similar state agencies may designate critical or suitable habitat areas that they believe are necessary for the survival of threatened or endangered species. Such a designation could materially restrict use of or access to federal, state and private lands.

Risks Related to Desert Peak’s Financial and Debt Arrangements

Restrictions in Desert Peak’s current and future debt agreements and credit facilities could limit its growth and its ability to engage in certain activities.

KMF Land, LLC (“KMF Land”), an indirect subsidiary of Kimmeridge, entered into a $750 million revolving credit facility on September 26, 2019 (as amended, restated, amended and restated, or otherwise modified prior to October 8, 2021, the “original credit facility”), which Desert Peak amended and restated on October 8, 2021 (as so amended and restated, the “revolving credit facility”), to, among other things, provide for an increased borrowing base.

Desert Peak’s revolving credit facility is available for working capital, acquisitions and general company purposes and is secured by substantially all of the assets of KMF Land, its direct parent and its subsidiaries. Desert Peak’s revolving credit facility contains certain customary representations and warranties and various covenants and restrictive provisions that limit KMF Land’s, its direct parent’s and its subsidiaries’ ability to, among other things:

 

   

incur or guarantee additional debt;

 

   

pay dividends on, or redeem or repurchase, their equity interests, return capital to the holders of their equity interests, or make other distributions to holders of their equity interests;

 

   

enter into certain swap arrangements;

 

   

make certain investments and acquisitions;

 

   

incur certain liens or permit them to exist;

 

   

enter into certain types of transactions with affiliates;

 

   

merge or consolidate with another company;

 

   

transfer, sell or otherwise dispose of assets;

 

   

enter into certain other lines of business; and

 

   

repay or redeem certain debt.

Desert Peak’s revolving credit facility also contains covenants requiring KMF Land, its direct parent and its subsidiaries to maintain certain financial ratios or to reduce its indebtedness if they are unable to comply with such ratios. Their ability to meet those financial ratios and tests can be affected by events beyond Desert Peak’s control. These restrictions may also limit Desert Peak’s ability to obtain future financings to withstand a future downturn in its business or the economy in general, or to otherwise conduct necessary corporate activities. Desert Peak may also be prevented from taking advantage of business opportunities that arise because of the limitations that the restrictive covenants under its revolving credit facility impose on it.

 

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A failure to comply with the provisions of Desert Peak’s revolving credit facility could result in an event of default, which could enable the lenders to declare, subject to the terms and conditions of Desert Peak’s revolving credit facility, any outstanding principal of that debt, together with accrued and unpaid interest, to be immediately due and payable. If the payment of the debt is accelerated, cash flows from Desert Peak’s operations may be insufficient to repay such debt in full. Desert Peak’s revolving credit facility contains events of default customary for transactions of this nature, including the occurrence of a change of control. Please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations of Desert Peak—Liquidity and Capital Resources—Our Revolving Credit Facility.”

Any significant reduction in the borrowing base under Desert Peak’s revolving credit facility as a result of the periodic borrowing base redeterminations or otherwise may negatively impact Desert Peak’s ability to fund its operations.

Desert Peak’s revolving credit facility limits the amounts Desert Peak can borrow up to a borrowing base amount, which the lenders, in their sole discretion, will unilaterally determine on a regular basis based in part upon projected revenues from the oil and natural gas properties securing the loans issued thereunder. If the borrowing base is reduced, Desert Peak may not have access to capital needed to fund its expenditures and it would be required to repay outstanding borrowings in excess of the borrowing base after applicable grace periods. Desert Peak may not have other collateral or the financial resources in the future to make mandatory principal prepayments required under its revolving credit facility, which could lead to a default.

Any significant contraction in the reserve-based lending syndication market may negatively impact Desert Peak’s ability to fund its operations.

Lending institutions have significantly curtailed reserved-based lending or entirely exited the reserve-based lending market. In the prevailing market, it may be difficult for the arrangers under Desert Peak’s revolving credit facility, or under any other potential future reserve-based credit facility, to obtain sufficient commitments for the borrowing base or to do so on terms favorable or acceptable to Desert Peak. Desert Peak has funded its operations since inception primarily through capital contributions and cash generated from operations, and it may finance acquisitions, and potentially other working capital needs, with borrowings under its revolving credit facility. Desert Peak intends to continue to make significant acquisitions to support its business growth. If the arrangers under Desert Peak’s revolving credit facility, or under any other potential future reserve-based credit facility, are unable to obtain sufficient commitments for the borrowing base, Desert Peak may not have sufficient funds to finance its operations and future growth. If adequate funds are not available, Desert Peak may be required to reduce expenditures, including curtailing its growth strategies or forgoing acquisitions.

In addition, during previous periods of economic instability, it has been difficult for many companies to obtain financing in the public markets or to obtain debt financing, and during any future period of economic instability Desert Peak may not be able to obtain additional financing on commercially reasonable terms, if at all. If Desert Peak is unable to obtain adequate financing or financing on terms satisfactory to it, Desert Peak could experience a material adverse effect on its business, financial condition and results of operations.

Desert Peak’s debt levels may limit its flexibility to obtain additional financing and pursue other business opportunities.

Desert Peak’s existing and any future indebtedness could have important consequences to it, including:

 

   

its ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may be impaired, or such financing may not be available on terms acceptable to it;

 

   

covenants in its revolving credit facility require, and in any future credit and debt arrangement may require, KMF Land or Desert Peak to meet financial tests that may affect its flexibility in planning for and reacting to changes in its business, including possible acquisition opportunities;

 

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its access to the capital markets may be limited;

 

   

its borrowing costs may increase;

 

   

it will use a portion of its discretionary cash flows to make principal and interest payments on its indebtedness, reducing the funds that would otherwise be available for operations, future business opportunities and payment of dividends to its stockholders; and

 

   

its debt level will make Desert Peak more vulnerable than its competitors with less debt to competitive pressures or a downturn in its business or the economy generally.

Desert Peak’s ability to service its indebtedness will depend upon, among other things, Desert Peak’s future financial and operating performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, some of which are beyond its control. If Desert Peak’s operating results are not sufficient to service its current or future indebtedness, Desert Peak will be forced to take actions such as reducing distributions, reducing or delaying business activities, acquisitions, investments and/or capital expenditures, selling assets, restructuring or refinancing its indebtedness, or seeking additional equity capital or bankruptcy protection. Desert Peak may not be able to effect any of these remedies on satisfactory terms or at all.

General Risk Factors

Increased costs of capital could adversely affect Desert Peak’s business.

Desert Peak’s business and ability to make acquisitions could be harmed by factors such as the availability, terms, and cost of capital, increases in interest rates or a reduction in its credit rating. Changes in any one or more of these factors could cause Desert Peak’s cost of doing business to increase, limit its access to capital, limit its ability to pursue acquisition opportunities, and place it at a competitive disadvantage. A significant reduction in the availability of capital could materially and adversely affect Desert Peak’s ability to achieve its planned growth and operating results.

Desert Peak may be involved in legal proceedings that could result in substantial liabilities.

Like many crude oil and natural gas companies, Desert Peak may from time to time be involved in various legal and other proceedings, such as title, royalty or contractual disputes, regulatory compliance matters and personal injury or property damage matters, in the ordinary course of its business. Such legal proceedings are inherently uncertain and their results cannot be predicted. Regardless of the outcome, such proceedings could have an adverse impact on Desert Peak because of legal costs, diversion of management and other personnel and other factors. In addition, it is possible that a resolution of one or more such proceedings could result in liability, penalties or sanctions, as well as judgments, consent decrees or orders requiring a change in Desert Peak’s business practices, which could materially and adversely affect its business, operating results and financial condition. Accruals for such liability, penalties or sanctions may be insufficient. Judgments and estimates to determine accruals or range of losses related to legal and other proceedings could change from one period to the next, and such changes could be material.

 

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Exhibit 99.8

INFORMATION ABOUT DESERT PEAK

Unless otherwise indicated, the historical financial and operating information presented in this “Information About Desert Peak” is that of Kimmeridge Mineral Fund, LP, Desert Peak’s predecessor for financial reporting purposes, and its consolidated subsidiaries (the “predecessor,” “KMF” or the “Partnership”), which includes the assets acquired in the Chambers Acquisition (as defined herein), the Rock Ridge Acquisition (as defined herein), the Source Acquisition (as defined herein), and the Recent Acquisitions (as defined herein) as of December 31, 2021. Unless otherwise indicated, references in this “Information About Desert Peak” to financial information on a “pro forma basis” refer to the historical financial information of KMF, as adjusted to give pro forma effect to (i) the Chambers Acquisition, (ii) the Rock Ridge Acquisition and (iii) the Source Acquisition, in each case as if the transaction occurred on January 1, 2021. Unless otherwise indicated, references in this “Information About Desert Peak” to operating information on a “pro forma basis” refer to the historical operating information of KMF, as adjusted to give pro forma effect to (i) the Chambers Acquisition, (ii) the Rock Ridge Acquisition, (iii) the Source Acquisition and (iv) the Recent Acquisitions, in each case as if such acquisitions occurred on January 1, 2021.

Overview

Desert Peak acquires, owns and manages mineral and royalty interests in the Permian Basin with the objective of generating cash flow from operations that can be distributed to shareholders as dividends and reinvested to expand its base of cash flow generating assets. Desert Peak’s assets are exclusively focused in the Permian Basin. Desert Peak benefits from cash flow growth through continued development of its mineral and royalty interests, free of capital costs and lease operating expenses. As of December 31, 2021, Desert Peak owned mineral and royalty interests representing over 105,000 NRAs when adjusted to a 1/8 royalty. For the year ended December 31, 2021, on a pro forma basis the average net daily production associated with Desert Peak’s mineral and royalty interests was 9,149 Boe/d barrels of oil equivalent per day (“BOE/d”) consisting of 4,816 barrels per day (“Bbls/d”) of oil, 15,966 million cubic feet per day (“Mcf/d”) of natural gas and 1,673 Bbls/d of NGLs. Since Desert Peak’s formation in November 2016, Desert Peak has accumulated its acreage position by making 180 acquisitions. Desert Peak expects to continue to grow its acreage position by making acquisitions that meet its investment criteria for geologic quality, operator capability, remaining growth potential, cash flow generation and, most importantly, rate of return.

As of December 31, 2021, approximately 95% of Desert Peak’s NRAs were located in West Texas where there are no federal lands, which means that operators on Desert Peak’s acreage are not subject to leasing, permitting, or easement authority from the federal government. The remaining 5% of Desert Peak’s NRAs are located in southeastern New Mexico. Desert Peak believes the Permian Basin offers some of the most compelling rates of return for oil and gas E&P companies and significant potential for mineral and royalty income growth. As a result of these compelling rates of return, development activity in the Permian Basin has outpaced all other onshore U.S. oil and gas basins since the end of 2016. This development activity has driven basin-level production to grow faster than production in the rest of the United States.

Desert Peak’s mineral and royalty interests entitle it to receive a fixed percentage of the revenue from crude oil, natural gas and NGLs produced from the acreage underlying its interests. Unlike owners of working interests in oil and gas properties, Desert Peak is not obligated to fund drilling and completion costs, plugging and abandonment costs or lease operating expenses associated with oil and gas production. As a mineral and royalty owner, Desert Peak incurs only its proportionate share of production and ad valorem taxes and, in some cases, gathering, processing and transportation costs. Accordingly, Desert Peak’s business generates strong margins, requires very low overhead and is highly scalable. For the year ended December 31, 2021, on a pro forma basis Desert Peak’s production and ad valorem taxes were approximately $2.61 per barrel of oil equivalent (“BOE”), relative to an average realized price of $45.74 per BOE. As a result, Desert Peak’s operating margin and cash flows are higher, as a percentage of revenue, than those of traditional E&P companies. On a pro forma basis, during the year ended December 31, 2021, Desert Peak generated net income of $62.7 million and Adjusted

 

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EBITDA of $133.4 million. Desert Peak does not anticipate engaging in any activities, other than acquisitions, that will incur capital costs.

Desert Peak has built its acreage position through the consummation of 180 acquisitions since November 2016. In addition to completing numerous small transactions, Desert Peak have completed a total of 14 transactions larger than 1,500 NRAs that account for approximately 85% of its NRAs, including the Chambers Acquisition of approximately 7,200 NRAs, the Rock Ridge Acquisition of approximately 18,500 NRAs and the Source Acquisition of approximately 25,000 NRAs. During the six years ended December 31, 2021, Desert Peak evaluated over 1,000 potential mineral and royalty interest acquisitions and completed 167 acquisitions from landowners and other mineral interest owners, representing 47,837 NRAs, to its asset base. During 2020, Desert Peak’s acquisition activity saw a significant decline following the onset of the COVID-19 global pandemic. Following the associated decline in oil prices during the onset of the pandemic, Desert Peak experienced a meaningful difference in sellers’ pricing expectations and the prices Desert Peak was willing to offer for assets. Desert Peak evaluated approximately 197,416 NRAs and submitted formal offers on 56,658 NRAs but did not consummate any acquisitions subsequent to the first quarter of 2020 through the end of the first quarter of 2021. However, Desert Peak utilized its significant free cash flow during 2020 to reduce its indebtedness from $66 million as of March 31, 2020 to $25.0 million as of March 31, 2021. Beginning in the second quarter of 2021, Desert Peak saw a meaningful increase in its acquisition activity as evidenced by the approximately 26,000 NRAs it acquired in the second quarter and the approximately 28,000 NRAs it acquired in the third quarter. The following table summarizes Desert Peak’s completed acquisitions from November 2016 through December 31, 2021.

 

Year

   Number of
Acquisitions
     Total
NRAs
Acquired
 

2016

     2        4,060  

2017

     50        18,037  

2018

     48        14,698  

2019

     67        11,042  

2020

     4        1,614  

2021

     9        55,908  
  

 

 

    

 

 

 

Total

     180        105,359  
  

 

 

    

 

 

 

Desert Peak is led by a management team with extensive oil and gas engineering, geologic and land expertise, mergers and acquisitions and capital markets experience, long-standing industry relationships and a history of successfully acquiring and managing a portfolio of leasehold interests, producing crude oil, natural gas and NGL assets, and mineral and royalty interests. Desert Peak intends to capitalize on its management team’s expertise and relationships to continue to make value-enhancing mineral and royalty interest acquisitions in the Permian Basin designed to increase its cash flows per share.

Desert Peak was founded by Kimmeridge. Kimmeridge is a private equity firm based in New York and Denver that is differentiated by its strategy of direct investment in unconventional oil and gas assets, leveraging its in-house expertise in geological evaluation, land acquisition and engineering. Kimmeridge and several members of Desert Peak’s management team founded and managed two Delaware Basin-focused E&P companies, Arris Petroleum (as defined below) and 299 Resources (as defined below), and successfully monetized those companies in 2016 by selling Kimmeridge’s ownership interests in those companies to PDC Energy (as defined below). Additionally, in October 2020, another private equity fund managed by Kimmeridge acquired a 2.0% (on an 8/8ths basis) ORRI in all of Callon Petroleum Company’s (“Callon”) operated assets in the Delaware, Midland and Eagle Ford Basins, which proportionately reduced Callon’s net revenue interest (“Chambers ORRI”). Subsequent to the transaction, Desert Peak’s management team managed the acquired ORRI. Desert Peak has leveraged Kimmeridge’s extensive Permian Basin experience and relationships with mineral and royalty owners in the region as Desert Peak has grown its acreage position, and Desert Peak expects

 

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to continue to do so in the future. Furthermore, Kimmeridge has established itself as a thought leader in the oil and gas industry, particularly around ESG matters, and Desert Peak’s philosophy is consistent with Kimmeridge’s views on, among other things, aligning management compensation with the interests of shareholders and maintaining strong governance practices. See “—ESG Philosophy.”

Desert Peak’s Key Producing Region

As of December 31, 2021, all of Desert Peak’s properties were located exclusively within the Permian Basin. As of December 31, 2021, the Permian Basin had the highest level of horizontal drilling activity in the United States, according to Baker Hughes. The Permian Basin includes three geologic provinces: the Delaware Basin to the west, the Midland Basin to the east and the Central Basin Platform in between. The Delaware Basin is identified by an abundant amount of oil-in-place, stacked pay potential across an approximately 3,900 foot hydrocarbon column, attractive well economics, favorable operating environment, well developed network of oilfield service providers and significant midstream infrastructure in place or actively under construction. The Midland Basin is also identified by an abundant amount of oil-in-place stacked pay potential across an approximately 3,500 foot hydrocarbon column, attractive well economics, favorable operating environment, well developed network of oilfield service providers and significant midstream infrastructure in place. There are no federal lands on the Texas side of the Delaware Basin, where approximately 95% of Desert Peak’s NRAs were located as of December 31, 2021, and therefore the acreage underlying Desert Peak’s Texas NRAs is not subject to federal government involvement in or regulation of leasing, permitting or easements. According to the USGS, the Delaware Basin contains the largest recoverable reserves among all unconventional basins in the United States.

Desert Peak believes the stacked-pay potential of the Delaware Basin combined with favorable drilling economics support continued production growth as E&P operators continue to develop their positions and improve well-spacing and completion techniques. Relative to other unconventional basins in the continental United States, Desert Peak believes the Delaware Basin is in an earlier stage of horizontal well development and that per-well returns will improve as E&P operators continue to employ advanced horizontal drilling and completion technologies on multi-well pads in the region. Desert Peak believes these factors will continue to support development activity in the region and in the areas where it holds mineral and royalty interests, leading to increasing cash flows free of lease operating expenses.

Desert Peak believes the stacked-pay potential of the Midland Basin combined with low cost supply driven by enhancements in drilling efficiency supports continued production growth. The Midland Basin is in a more mature phase of horizontal well development relative to other unconventional basins in the United States. Desert Peak believes these factors will continue to support development activity in the region and in the areas where it holds mineral and royalty interests, leading to increasing cash flows free of lease operating expenses. Desert Peak expects Midland Basin drilling efficiency to continue to improve as drilling days further compress and lateral lengths keep expanding.

Desert Peak’s Mineral and Royalty Interests

Desert Peak’s interests consist of mineral and royalty interests. Mineral interests, which represent approximately 82% of Desert Peak’s NRAs as of December 31, 2021, are real property interests that are typically perpetual and grant ownership of the crude oil and natural gas underlying a tract of land and the rights to explore for, drill for and produce crude oil and natural gas on that land or to lease those exploration and development rights to a third party. When Desert Peak leases those rights, usually for a one- to three-year term, Desert Peak typically receives an upfront cash payment, known as a lease bonus, and it retains a mineral royalty, which entitles it to a percentage (typically up to 25%) of production or revenue from production free of lease operating expenses. A lessee can extend the lease beyond the initial lease term with continuous drilling, production or other operating activities or through negotiated contractual lease extension options. When production and drilling cease, the lease terminates, allowing Desert Peak to lease the exploration and development rights to another party

 

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and receive another lease bonus. As of December 31, 2021, other types of royalty interests, non-participating royalty interests (“NPRIs”) and ORRIs, comprised approximately 5% and 13%, respectively, of Desert Peak’s NRAs. Also, as of December 31, 2021, approximately 86% of Desert Peak’s total NRAs, derived from mineral interests only, were leased to E&P operators and other working interest owners. As of December 31, 2021, approximately 95% of Desert Peak’s mineral and royalty interests are located in Texas and do not require federal approval to permit and drill oil and gas wells or to obtain easements or rights of way for operators to deliver their oil and gas to market. Desert Peak refers its mineral interests, NPRIs and ORRIs collectively as Desert Peak’s “mineral and royalty interests.” Desert Peak generates a substantial majority of its revenues and cash flows from its mineral and royalty interests when crude oil, natural gas and NGLs are produced from its acreage and sold by the applicable E&P operators and other working interest owners. Desert Peak’s predecessor’s pro forma revenue generated from these mineral and royalty interests was approximately $117.5 million for the year ended December 31, 2020 and $223.6 million for the year ended on December 31, 2021. Approximately 88% of 2020 and 83% of 2021 revenue was derived from the sale of oil and NGLs on a pro forma basis.

Currently, Desert Peak’s mineral and royalty interests reside entirely in the Permian Basin, which Desert Peak believes is one of the premier unconventional crude oil, natural gas and NGL producing regions in the United States. As of December 31, 2021, Desert Peak’s interests covered 56,595 net mineral acres, approximately 85% of which have been leased to E&P operators and other working interest owners with Desert Peak retaining an average 19.3% royalty. If Desert Peak were to lease its remaining unleased net mineral acres this would change to a 19.1% average royalty. Typically, within the mineral and royalty industry, owners standardize ownership of NRAs to a 12.5%, or a 1/8th, royalty interest, representing the number of equivalent acres earning a 12.5% royalty, which is referred to as an NRA. When adjusted to a 1/8th royalty, Desert Peak’s mineral interests represent 86,260 NRAs, and its NPRIs and ORRIs represent an additional 19,099 NRAs, totaling 105,359 NRAs in the aggregate. Desert Peak’s drilling spacing units (“DSUs”), in the aggregate, consist of a total of 1.38 million gross acres, which Desert Peak refers to as Desert Peak’s “gross DSU acreage.” Desert Peak expects to have an ownership interest in all wells that will be drilled within its gross DSU acreage in the future. The following table summarizes Desert Peak’s mineral and royalty interest position and the conversion of its interests from net mineral acres to NRAs and 100% royalty acres as of December 31, 2021.

 

Net Mineral
Acres

 

Average
Royalty

 

NRAs (Mineral
Interests)(1)(2)

 

NRAs (NPRIs)

 

NRAs (ORRIs)

 

Total NRAs

 

100% NRAs(3)

 

Gross DSU
Acres

 

Implied
Average Net
Revenue
Interest per
Well(4)

56,595   19.05%   86,260   5,325   13,774   105,359   13,170   1,379,873   1.0%

 

(1)

Desert Peak’s mineral interests are based on its average royalty interests across its net mineral acreage position normalized to reflect a 1/8th royalty interest per net mineral acre (i.e., NRAs from mineral and royalty interests are calculated by multiplying 56,595 net mineral acres multiplied by an average royalty of 19.05% and then divided by 12.5%).

(2)

All unleased mineral interests are assumed at a 25% royalty interest or 12.5% royalty interest on Relinquishment Act land.

(3)

Calculated as 105,359 NRAs multiplied by 12.5%.

(4)

Calculated as 13,170, 100% royalty acres divided by 1.38 MM gross DSU acres.

As of December 31, 2021, Desert Peak has interests in 659 (4.644 net) horizontal wells on which drilling has commenced but are not yet producing in paying quantities, which Desert Peak refers to as spud wells, and 533 (3.394 net) wells for which permits have been issued to the operators, but on which drilling has not yet commenced, which Desert Peak refers to as permitted wells. For the year ended December 31, 2021, Desert Peak’s permitted wells converted into spud wells within an average of 5.9 months and its spud wells converted into producing wells within an average of 7.6 months. The total time from permit to first production on Desert Peak’s producing wells was 13.5 months on average as compared to a total time of 14.6 months for the Permian Basin on average. Desert Peak’s Reserves and Production

 

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As of December 31, 2021, the estimated proved crude oil, natural gas and NGLs reserves attributable to Desert Peak’s interests in its underlying acreage were 24,592 thousands of BOE (“MBOE”) (68% liquids, consisting of 48% crude oil and 20% NGLs), based on a reserve report prepared by CG&A. Of these reserves, approximately 83% were classified as proved developed producing (“PDP”) reserves, 1% were classified as proved developed non-producing (“PDNP”) reserves and 17% were classified as PUD reserves. PUD reserves included in these estimates relate solely to wells that were spud but not yet producing in paying quantities as of December 31, 2021. Estimated proved reserves included in this “—Business” section are presented on an actual basis, without giving pro forma effect to transactions completed after such dates.

Desert Peak believes its production and discretionary cash flows will grow significantly as E&P operators drill the substantial undeveloped inventory of horizontal drilling locations located on its gross DSU acreage. As of December 31, 2021, Desert Peak had production from 4,459 (36.887 net) horizontal wells, and it has identified 16,298 (129.667) undeveloped horizontal drilling locations based on its assessment of current geological, engineering and land data, which is equivalent to 12.489 gross undeveloped horizontal drilling locations per one mile-wide DSU. Furthermore, Desert Peak believes there is potential for additional drilling activity through drilling efforts by its current E&P operators and through development of additional horizontal formations, including the Woodford/Barnett formations.

Desert Peak’s mineral interest investment strategy anticipates E&P operators shifting drilling activity from a focus on drilling single wells to hold acreage towards more drilling in each DSU, particularly on multi-well pads. As of December 31, 2021, Desert Peak’s position has an average of 3.47 gross producing horizontal wells per mile wide DSU, compared to its spacing assumption of 15.9 gross wells per DSU. Furthermore, Desert Peak expects to see increases in its production, revenue and discretionary cash flows from the development of

659 spud wells and 533 permitted wells across its interests as of December 31, 2021, compared to 546 gross wells completed on its acreage in the year ended December 31, 2021. If all of Desert Peak’s spud wells were completed and all of its permitted wells were drilled and completed, Desert Peak expects that its gross producing horizontal wells per mile wide DSU would increase from 3.47 to 4.38. Desert Peak believes its current interests provide the potential for significant long-term organic revenue growth as E&P operators develop its acreage and utilize advancements in drilling and completion techniques to increase crude oil, natural gas and NGL production.

Desert Peak’s E&P Operators

In addition to utilizing technical analysis to identify attractive mineral and royalty interests in the prolific Permian Basin, Desert Peak’s management team strives to acquire mineral and royalty interests in properties with top-tier E&P operators. Desert Peak seeks E&P operators that are well-capitalized, have a strong operational track record, and that Desert Peak believes will continue to increase production through the application of the latest drilling and completion techniques across its mineral and royalty interests. Approximately 58 horizontal E&P operators are currently producing oil and gas from Desert Peak’s acreage. The chart below summarizes the E&P operators of Desert Peak’s acreage based on revenue received in the year ended December 31, 2021.

 

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LOGO

ESG Philosophy

Since Desert Peak’s inception, Kimmeridge and Desert Peak have been committed to all three elements of ESG and are in the process of developing appropriate ESG policies, including strong governance policies. Desert Peak’s fully staffed, experienced team will be dedicated solely to its business of pursuing and consummating acquisitions. The Desert Peak board of directors and employee base are reflective of a culture that values diversity, with approximately one-half of Desert Peak’s employees being women or minorities. Desert Peak targets minerals under operators with strong environmental track records. Desert Peak prioritizes responsible environmental practices and it endeavors to prohibit flaring by the operator in each lease. As Desert Peak continues to gain additional scale, it intends to further pressure operators to eliminate flaring and venting of methane.

Recent Acquisitions

Chambers Acquisition

On June 7, 2021, Desert Peak completed the acquisition of the Delaware Basin portion of the Chambers ORRI from Chambers Minerals, LLC, an affiliate of Kimmeridge (the “Chambers Acquisition”), which represents approximately 7,200 NRAs consisting of a 2.0% (on an 8/8ths basis) ORRI, proportionately reduced to Callon’s net revenue interest, in substantially all Callon-operated oil and gas leasehold in the Delaware Basin.

Rock Ridge Acquisition

On June 30, 2021, Desert Peak completed the acquisition of approximately 18,500 NRAs in the Delaware Basin from Rock Ridge (the “Rock Ridge Acquisition”), a limited liability company formed by investment funds affiliated with Blackstone Inc. (“Blackstone”).

Source Acquisition

On August 31, 2021, Desert Peak completed the acquisition of approximately 25,000 NRAs (the “Source Assets”) in the Midland and Delaware Basins from the Source Stockholders ( the “Source Acquisition”), limited partnerships backed by investment funds affiliated with Oaktree Capital Management, L.P. (“Oaktree”).

The Source Assets consist of approximately 21,500 NRAs located in the Midland Basin and 3,500 NRAs located in the Delaware Basin. For the six months ended June 30, 2021, production associated with the Source Assets was 1,612 BOE/d.

 

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Other Acquisitions

Subsequent to December 31, 2020, in addition to the Chambers Acquisition, the Rock Ridge Acquisition and the Source Acquisition, Desert Peak has (i) completed multiple acquisitions totaling approximately 146 NRAs in the Delaware Basin from private, unrelated sellers, each of which closed prior to June 30, 2021 and (ii) on July 26, 2021, acquired approximately 3,500 additional NRAs from a private third-party seller (the “Recent Acquisitions”).

Business Strategies

Desert Peak’s primary business objective is to generate discretionary cash flow by acquiring mineral and royalty interests in the Permian Basin with the most significant potential rates of return for upstream E&P operators to maximize the likelihood that drilling and production will occur. Desert Peak intends to accomplish this objective by executing the following strategies:

 

   

Generate strong discretionary cash flow supported by disciplined acquisition strategy. As mineral and royalty interest owners, Desert Peak benefits from the continued organic development of its acreage in the Permian Basin and is able to convert a high percentage of its revenue to discretionary cash flow, which it defines as its Adjusted EBITDA less cash interest expense and cash taxes. Desert Peak does not incur operating costs for the production of crude oil and natural gas or capital costs for the drilling and completion of wells on its acreage. Desert Peak’s only cash operating costs related to its mineral and royalty business consist of certain taxes, gathering, processing and transportation costs, and general and administrative expenses. For the year ended December 31, 2021, on a pro forma basis Desert Peak’s production and ad valorem taxes were approximately $2.61 per BOE, relative to an average realized price of $45.74 per BOE. Desert Peak believes that its royalty interests are positioned for discretionary cash flow growth as E&P operator focus continues to shift to the Permian Basin, as evidenced by the increase in the percentage of total U.S. onshore rigs located in the Permian Basin over the last three years. Desert Peak expects to continue to grow its acreage position by making acquisitions that meet its investment criteria for geologic quality, operator capability, remaining growth potential, cash flow generation and, most importantly, rate of return.

 

   

Focus primarily on the Permian Basin. All of Desert Peak’s mineral and royalty interests are currently located in the Permian Basin, one of the most prolific oil and gas basins in the United States. Desert Peak believes the Permian Basin provides an attractive combination of highly-economic and oil-weighted geologic and reservoir properties, opportunities for development with significant inventory of drilling locations and zones to be delineated and top-tier, well-funded E&P operators.

 

   

Leverage expertise and relationships to continue acquiring Permian Basin mineral and royalty interests associated with top-tier E&P operators. Desert Peak has a history of evaluating, pursuing and consummating acquisitions of crude oil and natural gas mineral and royalty interests in the Permian Basin. Since November 2016, Desert Peak has completed more than 180 acquisitions, demonstrating its ability to add scale quickly and effectively. Desert Peak’s management team intends to continue to apply this experience in a disciplined manner when identifying and acquiring mineral and royalty interests. Desert Peak believes that the current market environment is favorable for the consolidation of mineral and royalty interests, as the disaggregated nature of asset packages from numerous sellers presents attractive opportunities for assets that meet its target investment criteria. With sellers seeking to monetize their investments but lacking the scale to do so in the public markets, Desert Peak intends to continue to acquire mineral and royalty interests that have substantial resource potential in the Permian Basin, an area that it expects to continue to experience a relatively high rate of development, with E&P operators incentivized to economically deploy capital to delineate and develop their positions over the underlying mineral interests. This E&P operator activity creates an opportunity for organic growth free of lease operating and capital expenses. Desert Peak expects to focus on acquisitions that complement its current footprint in the Permian Basin while targeting mineral and royalty interests underlying the acreage of well-capitalized E&P operators that have a history of high

 

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conversion rates of permits issued to wells completed on large contiguous acreage positions. Furthermore, Desert Peak seeks to maximize its return on capital by targeting acquisitions that meet the following criteria:

 

   

sufficient visibility to production growth;

 

   

attractive economics;

 

   

de-risked geology supported by offsetting production;

 

   

top-tier E&P operators; and

 

   

a geographic footprint that Desert Peak believes is complementary to its diverse portfolio of Permian Basin assets and maximizes its potential for upside reserve and production growth.

 

   

Maintain conservative and flexible capital structure to support Desert Peak’s business and facilitate long-term operations. Desert Peak is committed to maintaining a conservative capital structure that will afford it the financial flexibility to execute its business strategies on an ongoing basis. Desert Peak believes that internally generated cash flows from operations, available borrowing capacity under its revolving credit facility, and access to capital markets will provide it with sufficient liquidity and financial flexibility to continue to acquire attractive mineral and royalty interests that will position it to grow its cash flows and return capital to stockholders. Desert Peak intends to maintain a conservative leverage profile and utilize a mix of cash flows from operations and issuance of debt and equity securities to finance future acquisitions.

Competitive Strengths

Desert Peak believes that the following competitive strengths will allow it to successfully execute its business strategies and achieve its primary business objective:

 

   

Differentiated energy investment opportunity. As opposed to traditional E&P operators who require significant capital, Desert Peak’s business requires no drilling and completion capital, lease operating expenses or plugging and abandonment costs at the end of a well’s productive life and accordingly represents a differentiated energy investment opportunity. In addition, Desert Peak is not responsible for environmental or other operational liabilities in connection with oil and gas production associated with its interests, and its only operating cash costs related to its mineral and royalty business consist of certain production taxes, gathering, processing and transportation costs and general and administrative expenses. For example, for the year ended December 31, 2021, on a pro forma basis Desert Peak’s production and ad valorem taxes were approximately $2.61 per BOE, relative to an average realized price of $45.74 per BOE. Furthermore, Desert Peak has significantly reduced its indebtedness during the COVID-19 pandemic, while many other energy companies struggled with indebtedness and leverage issues during 2020. Desert Peak believe its low capital requirements and financial discipline will result in an ability to distribute a meaningful amount of cash flow to stockholders.

 

   

Permian Basin focused public minerals company positioned as a preferred buyer in the basin. Desert Peak believes that its focus on the Permian Basin will position it as a preferred buyer of Permian Basin mineral and royalty interests. After giving effect to the Merger Transactions, over 75% of the Post-Combination Company’s NRAs will be located in the Permian Basin, one of the most prolific oil plays in the United States, and the majority of its current properties are well positioned in areas with proven results from multiple stacked productive zones. Desert Peak’s properties in the Permian Basin are high-quality, high-margin, and oil- and liquids-weighted, and it believes they will be viewed favorably by sellers interested in receiving equity consideration in exchange for their assets as compared to equity consideration diluted by lower quality assets located in less prolific basins.

 

   

Favorable and stable operating environment in the Permian Basin. With over 400,000 wells drilled in the Permian Basin since 1900, the region features a reliable and predictable geological and regulatory environment, according to Enverus. Desert Peak believes that the impact of new technology, combined with the substantial geological information available about the Permian Basin, also reduces the risk of

 

8


 

development and exploration activities as compared to other, emerging hydrocarbon basins. As of December 31, 2021, approximately 95% of Desert Peak’s acreage was located in Texas and does not require federal approval to permit and drill oil and gas wells or to grant easements to allow E&P operators to deliver their production to market.

 

   

Experienced management team with an extensive track record of minerals acquisitions. The members of Desert Peak’s management team have grown its acreage position through the consummation of 180 acquisitions since November 2016 ranging in size from small transactions of less than 25 NRAs to large transactions in excess of 1,500 NRAs, including the Chambers Acquisition of approximately 7,200 NRAs, the Rock Ridge Acquisition of approximately 18,500 NRAs and the Source Acquisition of approximately 25,000 NRAs. Notably, Desert Peak has acquired nearly 85% of Desert Peak’s NRAs through 14 large acquisitions, using both cash and equity consideration to suit the needs of sellers. Desert Peak’s management team has deep industry experience focused on resource play development in the Permian Basin and has a track record of identifying mineral and royalty acquisition targets, negotiating agreements, and successfully consummating acquisitions. Desert Peak plans to continue to evaluate and pursue acquisitions of all sizes. Desert Peak expects to benefit from the industry relationships fostered by its management team’s decades of experience in the oil and natural gas industry with a focus on the Permian Basin, in addition to leveraging its relationship with Kimmeridge.

 

   

Development potential of the properties underlying Desert Peak’s Permian Basin mineral and royalty interests. Desert Peak’s assets consist of mineral and royalty interests located in the Permian Basin, and Desert Peak expects production from its mineral and royalty interests to increase as E&P operators continue to actively drill and develop its acreage. Relative to other unconventional basins in the continental United States, Desert Peak believes the Permian Basin is in an earlier stage of development and that the average number of producing wells per section in the Permian Basin will increase as E&P operators continue to optimize drilling locations and delineate additional zones, which would allow Desert Peak to achieve higher realized cash flows per net mineral acre. Desert Peak targets acquisitions of properties that are relatively undeveloped in the core of the Delaware Basin, and it believes the organic development of its acreage will result in substantial production growth regardless of acquisition activity. From January 1, 2016 to September 30, 2021, production attributable to Desert Peak’s properties increased at a CAGR of 37% assuming its NRAs as of December 31, 2020 were owned on January 1, 2016, as compared to a CAGR of 23% for Permian Basin production growth generally and a CAGR of 8% for total U.S. onshore production growth for the same period.

 

   

Diverse group of blue-chip E&P operators on Desert Peak’s mineral and royalty interests driving production growth. Desert Peak’s mineral and royalty interests consist of properties operated by established E&P companies, such as Occidental Petroleum Corporation, BP plc, Coterra Energy Inc., Conoco Phillips and Chevron Corporation. Desert Peak’s blue-chip E&P operators provide a diversified source of revenues, as no single E&P operator provided greater than 12% of Desert Peak’s total revenues for the year ended December 31, 2021.

Crude Oil, Natural Gas and NGLs Data

The information included in “—Crude Oil, Natural Gas and NGLs Data” and “—Crude Oil, Natural Gas and NGL Production Prices and Costs” presents Desert Peak’s reserves and operating data as of and for the years ended December 31, 2021 and 2020 on an actual basis, without giving pro forma effect to transactions completed after such dates. As such, the reserves and operating data as of and for the year ended December 31, 2020 presented in these sections does not give effect to the Chambers Acquisition, the Rock Ridge Acquisition, the Source Acquisition or the Recent Acquisitions. The assets acquired in the Chambers Acquisition, the Rock Ridge Acquisition, the Source Acquisition and the Recent Acquisitions are included in Desert Peak’s reserves and operating data as of December 31, 2021, and operating data attributable to the assets acquired in such acquisitions is included since the date of each respective acquisition for the year ended December 31, 2021 on an actual basis.

 

9


Preparation of Reserve Estimates

Desert Peak’s reserve estimates as of December 31, 2021 and 2020 are based on evaluations prepared by the independent petroleum engineering firm of CG&A in accordance with Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Evaluation Engineers and definitions and guidelines established by the SEC. Desert Peak selected CG&A as its independent reserve engineer for its historical experience and geographic expertise in engineering similar resources.

In accordance with rules and regulations of the SEC applicable to companies involved in crude oil and natural gas producing activities, proved reserves are those quantities of crude oil and natural gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations. The term “reasonable certainty” means deterministically, the quantities of crude oil and/or natural gas are much more likely to be achieved than not, and probabilistically, there should be at least a 90% probability of recovering volumes equal to or exceeding the estimate. All of Desert Peak’s proved reserves were estimated using a deterministic method. The estimation of reserves involves two distinct determinations. The first determination results in the estimation of the quantities of recoverable crude oil and natural gas and the second determination results in the estimation of the uncertainty associated with those estimated quantities in accordance with the definitions established under SEC rules. The process of estimating the quantities of recoverable reserves relies on the use of certain generally accepted analytical procedures. These analytical procedures fall into four broad categories or methods: (i) production performance-based methods, (ii) material balance-based methods; (iii) volumetric-based methods and (iv) analogy. These methods may be used singularly or in combination by the reserve evaluator in the process of estimating the quantities of reserves. Reserves for proved developed producing wells were estimated using production performance methods for the vast majority of properties. Certain new producing properties with

 

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very little production history were forecast using a combination of production performance and analogy to similar production, both of which are considered to provide a reasonably high degree of accuracy. Non-producing reserve estimates, for developed and undeveloped properties, were forecast using analogy methods. This method provides a reasonably high degree of accuracy for predicting PDNP and PUDs for Desert Peak’s properties due to the abundance of analog data.

To estimate economically recoverable proved reserves and related future net cash flows, Desert Peak considered many factors and assumptions, including the use of reservoir parameters derived from geological and engineering data that cannot be measured directly, economic criteria based on current costs and the SEC pricing requirements and forecasts of future production rates.

Under SEC rules, reasonable certainty can be established using techniques that have been proven effective by actual production from projects in the same reservoir or an analogous reservoir or by other evidence using reliable technology that establishes reasonable certainty. Reliable technology is a grouping of one or more technologies (including computational methods) that have been field tested and have been demonstrated to provide reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation. To establish reasonable certainty with respect to Desert Peak’s estimated proved reserves, the technologies and economic data used in the estimation of its proved reserves have been demonstrated to yield results with consistency and repeatability, and include production and well test data, downhole completion information, geologic data, electrical logs, radioactivity logs, core data, and historical well cost and operating expense data.

Internal Controls

Desert Peak’s internal staff of petroleum engineers and geoscience professionals work closely with its independent reserve engineer to ensure the integrity, accuracy and timeliness of data furnished to such independent reserve engineer in their preparation of reserve estimates. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation. As a result, the estimates of different engineers often vary. In addition, the results of drilling, testing and production may justify revisions of such estimates. Accordingly, reserve estimates often differ from the quantities of oil, natural gas and NGLs that are ultimately recovered. Desert Peak’s engineering group is responsible for the internal review of reserve estimates and includes the Vice President of Engineering and Acquisitions. Desert Peak’s Vice President of Engineering and Acquisitions is primarily responsible for overseeing the preparation of its reserve estimates and has more than 16 years of experience as an engineer. Desert Peak’s Chief Executive Officer is directly responsible for overseeing the engineering group.

No portion of Desert Peak’s engineering group’s compensation is directly dependent on the quantity of reserves booked. The engineering group reviews the estimates with the third-party petroleum consultant, CG&A, an independent petroleum engineering firm.

CG&A is a Texas Registered Engineering Firm (F-693), made up of independent registered professional engineers and geologists that have provided petroleum consulting services to the oil and gas industry for over 50 years. The lead evaluator that prepared Desert Peak’s reserve report was Zane Meekins at CG&A. Mr. Meekins has been a practicing consulting petroleum engineer at CG&A since 1989. Mr. Meekins is a Registered Professional Engineer in the State of Texas (License No. 71055) and has over 34 years of practical experience in petroleum engineering, with over 32 years of experience in the estimation and evaluation of reserves. He graduated from Texas A&M University in 1987 with a Bachelor of Science degree in Petroleum Engineering. Mr. Meekins meets or exceeds the education, training and experience requirements set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of

 

11


Petroleum Engineers; he is proficient in judiciously applying industry standard practices to engineering and geoscience evaluations as well as applying SEC and other industry reserve definitions and guidelines.

Summary of Reserves

The following table presents Desert Peak’s estimated proved reserves as of December 31, 2021 and 2020. The reserve estimates presented in the table below are based on reports prepared by CG&A, Desert Peak’s independent petroleum engineers, which reports were prepared in accordance with current SEC rules and regulations regarding oil and natural gas reserve reporting:

 

     December
31,
2021(1)
     December
31,
2020(2)
 

Estimated proved developed reserves:

     

Crude oil (MBbls)

     9,285        3,731  

Natural gas (MMcf)

     40,747        19,505  

NGLs (MBbls)

     4,417        2,352  
  

 

 

    

 

 

 

Total (MBOE)

     20,493        9,334  
  

 

 

    

 

 

 

Estimated proved undeveloped reserves:

     

Crude oil (MBbls)

     2,559        1,344  

Natural gas (MMcf)

     5,596        3,897  

NGLs (MBbls)

     607        473  
  

 

 

    

 

 

 

Total (MBOE)

     4,098        2,467  
  

 

 

    

 

 

 

Estimated proved reserves:

     

Crude oil (MBbls)

     11,844        5,075  

Natural gas (MMcf)

     46,343        23,402  

NGLs (MBbls)

     5,023        2,825  
  

 

 

    

 

 

 

Total (MBOE)

     24,592        11,800  
  

 

 

    

 

 

 

 

(1)

Desert Peak’s estimated proved reserves were determined using average first-day-of-the-month prices for the prior 12 months in accordance with SEC guidance. For crude oil and NGL volumes, the average WTI posted price of $66.56 per Bbl as of December 31, 2021 was adjusted for quality, transportation fees and a regional price differential. NGL price was modeled at 45.3% of the WTI posted price. For natural gas volumes, the average Henry Hub spot price of $3.598 per MMBtu as of December 31, 2021 was adjusted for energy content, transportation fees and a regional price differential. The average adjusted product prices weighted by production over the remaining lives of the proved properties are $66.34 per Bbl of crude oil, $30.14 per Bbl of NGL and $3.35 per Mcf of natural gas as of December 31, 2021.

(2)

Desert Peak’s estimated proved reserves were determined using average first-day-of-the-month prices for the prior 12 months in accordance with SEC guidance. For crude oil and NGL volumes, the average WTI posted price of $39.57 per Bbl as of December 31, 2020 was adjusted for quality, transportation fees and a regional price differential. NGL price was modeled at 27.8% of the WTI posted price. For natural gas volumes, the average Henry Hub spot price of $1.985 per MMBtu as of December 31, 2020 was adjusted for energy content, transportation fees and a regional price differential. The average adjusted product prices weighted by production over the remaining lives of the proved properties are $36.28 per Bbl of crude oil, $11.01 per Bbl of NGL and $1.02 per Mcf of natural gas as of December 31, 2020.

Reserve engineering is a process of estimating volumes of economically recoverable crude oil and natural gas that cannot be measured in an exact manner. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation. As a result, the estimates of

 

12


different engineers often vary. In addition, the results of drilling, testing, and production may justify revisions of such estimates. Accordingly, reserve estimates often differ from the quantities of crude oil and natural gas that are ultimately recovered. Estimates of economically recoverable crude oil and natural gas and of future net revenues are based on a number of variables and assumptions, all of which may vary from actual results, including geologic interpretation, prices, and future production rates and costs. Please read “Other Risk Factors of Desert Peak.”

PUDs

As of December 31, 2021, Desert Peak estimated its PUD reserves to be 2,559 MBbls of crude oil, 5,596 MMcf of natural gas and 606 MMbls of NGLs, for a total of 4,098 MBOE. As of December 31, 2020, Desert Peak estimated its PUD reserves to be 1,344 MBbls of crude oil, 3,897 MMcf of natural gas and 473 MBbls of NGLs, for a total of 2,467 MBOE. PUDs will be converted from undeveloped to developed as the applicable wells begin production. PUD reserves included in these estimates relate solely to wells that have been spud but are not yet producing as of the date of the report.

The following tables summarize Desert Peak’s changes in PUD reserves during the year ended December 31, 2021 (in MBOE):

 

     Proved
Undeveloped
Reserves
(MBOE)
 

Balance, December 31, 2020

     2,467  

Acquisitions of Reserves

     3,265  

Extensions and Discoveries

     626  

Revisions of Previous Estimates

     (451

Transfers to Estimated Proved Developed

     (1,808
  

 

 

 

Balance, December 31, 2021

     4,099  
  

 

 

 

Changes in Desert Peak’s PUD reserves that occurred during the year ended December 31, 2021 were primarily due to the following:

 

   

the acquisition of additional mineral and royalty interests located in the Delaware Basin in multiple transactions, which included 3,265 MBOE of additional PUDs;

 

   

well additions, extensions and discoveries of approximately 626 MBOE, as 112 horizontal well locations were converted to proved undeveloped;

 

   

negative volume revisions of 451 MBOE due to adjustments in expected well ownership;

 

   

and the conversion of approximately 1,808 MBOE in PUD reserves into proved developed reserves as 118 horizontal locations were drilled and completed.

As a mineral and royalty interests owner, Desert Peak does not incur any capital expenditures or lease operating expenses in connection with the development of its PUDs, which costs are borne entirely by the E&P operator. As a result, during the twelve months ended December 31, 2021, Desert Peak had no expenditures to convert PUDs to proved developed reserves.

Desert Peak identifies drilling locations based on its assessment of current geologic, engineering and land data. This includes DSU formation and current well spacing information derived from state agencies and the

 

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operations of the E&P companies drilling Desert Peak’s mineral and royalty interests. Desert Peak limits its PUDs solely to wells that have been spud but are not yet producing. As of December 31, 2021, approximately 17% of Desert Peak’s total proved reserves were classified as PUDs.

Crude Oil, Natural Gas and NGL Production Prices and Costs

Production and Price History

The following table sets forth information regarding net production of crude oil, natural gas and NGLs, and certain price and cost information for each of the periods indicated:

 

     Year Ended
December 31,
 
     2021      2020  

Production data:

     

Crude oil (MBbls)

     1,261        933  

Natural gas (MMcf)

     4,746        4,134  

NGLs (MBbls)

     499        488  
  

 

 

    

 

 

 

Total (MBOE)

     2,551        2,110  
  

 

 

    

 

 

 

Average realized prices:

     

Crude oil (per Bbl)

   $ 67.29      $ 37.40  

Natural gas (per Mcf)

   $ 3.61      $ 1.03  

NGLs (per Bbl)

   $ 33.22      $ 10.32  
  

 

 

    

 

 

 

Total (per BOE)(1)

   $ 46.47      $ 20.95  
  

 

 

    

 

 

 

Average cost (per BOE):

     

Production and ad valorem taxes

   $ 2.69      $ 1.49  

 

(1)

“Btu-equivalent” production volumes are presented on an oil-equivalent basis using a conversion factor of six Mcf of natural gas per Bbl of “oil equivalent,” which is based on approximate energy equivalency and does not reflect the price or value relationship between crude oil and natural gas.

Drilling Results

Productive wells consist of producing horizontal wells, wells capable of production and exploratory, development or extension wells that are not dry wells. As of December 31, 2021 and 2020, Desert Peak owned mineral and royalty interests in 4,459 and 1,650 productive horizontal wells. Desert Peak does not own any working interests in any wells other than in one plugged and abandoned well. Accordingly, Desert Peak does not own any net wells as such term is defined by Item 1208(c)(2) of Regulation S-K. However, based on its net revenue interest per well, as of December 31, 2021 and 2020, Desert Peak had the equivalent of 36.887 and 17.767 net producing horizontal wells on its acreage.

Desert Peak is not aware of any dry holes drilled on the acreage underlying its mineral and royalty interests during the relevant periods.

Acreage

The following table sets forth information relating to Desert Peak’s acreage for its mineral and royalty interests as of December 31, 2021:

 

Basin

 

Gross DSU
Acreage

 

Total NRAs

 

100% NRAs

 

Gross DSU
Developed
Acreage

 

Gross DSU
Undeveloped
Acreage

 

NRAs
(Developed)

 

NRAs
(Undeveloped)

Delaware

 

1,379,873

 

105,359

 

13,170

 

354,444

 

1,025,428

 

24,704

 

80,655

 

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Mineral interests comprised approximately 82% of our NRAs, ORRIs comprised approximately 13% of our NRAs and NPRIs comprised approximately 5% of our NRAs as of December 31, 2021. For information regarding the impact of lease expirations on our interests, please see “Risk Factors — Risk Factors Related to Desert Peak—Risks Related to Desert Peak’s Business — Acreage must be drilled before lease expiration, generally within three to five years, in order to hold the acreage by production. Desert Peak’s E&P operators’ failure to drill sufficient wells to hold acreage may result in the deferral of prospective drilling opportunities. In addition, Desert Peak’s ORRIs may be lost if the underlying acreage is not drilled before the expiration of the applicable lease or if the lease otherwise terminates.”

Regulation

The following disclosure describes regulation directly associated with E&P operators of crude oil and natural gas properties, including Desert Peak’s current E&P operators, and other owners of working interests in crude oil and natural gas properties.

Crude oil and natural gas operations are subject to various types of legislation, regulation and other legal requirements enacted by governmental authorities. This legislation and regulation affecting the crude oil and natural gas industry is under constant review for amendment or expansion. Some of these requirements carry substantial penalties for failure to comply. The regulatory burden on the crude oil and natural gas industry increases the cost of doing business.

Environmental Matters

Crude oil and natural gas exploration, development and production operations are subject to stringent laws and regulations governing the discharge of materials into the environment or otherwise relating to protection of the environment or occupational health and safety. These laws and regulations have the potential to impact production on the properties in which Desert Peak owns mineral interests, which could materially adversely affect its business and its prospects. Numerous federal, state and local governmental agencies, such as the EPA, issue regulations that often require difficult and costly compliance measures that carry substantial administrative, civil and criminal penalties and may result in injunctive obligations for non-compliance. These laws and regulations may require the acquisition of a permit before drilling commences, restrict the types, quantities and concentrations of various substances that can be released into the environment in connection with drilling and production activities, limit or prohibit construction or drilling activities on certain lands lying within wilderness, wetlands, ecologically sensitive and other protected areas, require action to prevent or remediate pollution from current or former operations, such as plugging abandoned wells or closing earthen pits, result in the suspension or revocation of necessary permits, licenses and authorizations, require that additional pollution controls be installed and impose substantial liabilities for pollution resulting from operations. The strict, joint and several liability nature of such laws and regulations could impose liability upon the E&P operators of Desert Peak’s properties regardless of fault. Moreover, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the release of hazardous substances, hydrocarbons or other waste products into the environment. Changes in environmental laws and regulations occur frequently, and any changes that result in more stringent and costly pollution control or waste handling, storage, transport, disposal or cleanup requirements could materially adversely affect Desert Peak’s business and prospects.

Non-Hazardous and Hazardous Waste

The Resource Conservation and Recovery Act (“RCRA”), and comparable state statutes and regulations promulgated thereunder, affect crude oil and natural gas exploration, development, and production activities by imposing requirements regarding the generation, transportation, treatment, storage, disposal and cleanup of hazardous and non-hazardous wastes. With federal approval, the individual states administer some or all of the provisions of RCRA, sometimes in conjunction with their own, more stringent requirements. Administrative,

 

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civil and criminal penalties can be imposed for failure to comply with waste handling requirements. Although most wastes associated with the exploration, development and production of crude oil and natural gas are exempt from regulation as hazardous wastes under RCRA, these wastes typically constitute nonhazardous solid wastes that are subject to less stringent requirements. From time to time, the EPA and state regulatory agencies have considered the adoption of stricter disposal standards for nonhazardous wastes, including crude oil and natural gas wastes. Moreover, it is possible that some wastes generated in connection with E&P of oil and gas that are currently classified as nonhazardous may, in the future, be designated as “hazardous wastes,” resulting in the wastes being subject to more rigorous and costly management and disposal requirements. On May 4, 2016, a coalition of environmental groups filed a lawsuit against EPA in the U.S. District Court for the District of Columbia for failing to update its RCRA Subtitle D criteria regulations governing the disposal of certain crude oil and natural gas drilling wastes. In December 2016, EPA and the environmental groups entered into a consent decree to address EPA’s alleged failure. In response to the consent decree, in April 2019, the EPA signed a determination that revision of the regulations is not necessary at this time. However, any changes in the laws and regulations could have a material adverse effect on the E&P operators of Desert Peak’s properties’ capital expenditures and operating expenses, which in turn could affect production from the acreage underlying Desert Peak’s mineral and royalty interests and adversely affect Desert Peak’s business and prospects.

Remediation

The Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”) and analogous state laws generally impose strict, joint and several liability, without regard to fault or legality of the original conduct, on classes of persons who are considered to be responsible for the release of a “hazardous substance” into the environment. These persons include the current owner or operator of a contaminated facility, a former owner or operator of the facility at the time of contamination, and those persons that disposed or arranged for the disposal of the hazardous substance at the facility. Under CERCLA and comparable state statutes, persons deemed “responsible parties” may be subject to strict, joint and several liability for the costs of removing or remediating previously disposed wastes (including wastes disposed of or released by prior owners or operators) or property contamination (including groundwater contamination), for damages to natural resources and for the costs of certain health studies. In addition, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the hazardous substances released into the environment. In addition, the risk of accidental spills or releases could expose the operators of the acreage underlying Desert Peak’s mineral interests to significant liabilities that could have a material adverse effect on the operators’ businesses, financial condition and results of operations. Liability for any contamination under these laws could require the operators of the acreage underlying Desert Peak’s mineral interests to make significant expenditures to investigate and remediate such contamination or attain and maintain compliance with such laws and may otherwise have a material adverse effect on their results of operations, competitive position or financial condition.

Water Discharges

The Clean Water Act (“CWA”), the SDWA, the Oil Pollution Act of 1990 (“OPA”), and analogous state laws and regulations promulgated thereunder impose restrictions and strict controls regarding the unauthorized discharge of pollutants, including produced waters and other crude oil and natural gas wastes, into regulated waters. The definition of regulated waters has been the subject of significant controversy in recent years, with different definitions proposed under the Obama and Trump Administrations. Both of these definitions have been subject to litigation, and the EPA and the U.S. Army Corps of Engineers have published a proposed rulemaking to revoke the 2020 rule in favor of a pre-2015 definition until a new definition is proposed, which the Biden Administration has announced is underway. To the extent any future rule expands the scope of jurisdiction, it may impose greater compliance costs or operational requirements on Desert Peak’s operators. The discharge of pollutants into regulated waters is prohibited, except in accordance with the terms of a permit issued by the EPA or the state. The CWA and regulations implemented thereunder also prohibit the discharge of dredge and fill material into regulated waters, including jurisdictional wetlands, unless authorized by an appropriately issued

 

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permit. In addition, spill prevention, control and countermeasure plan requirements under federal law require appropriate containment berms and similar structures to help prevent the contamination of navigable waters in the event of a petroleum hydrocarbon tank spill, rupture or leak. The EPA has also adopted regulations requiring certain crude oil and natural gas E&P facilities to obtain individual permits or coverage under general permits for storm water discharges, and in June 2016, the EPA finalized effluent limitation guidelines for the discharge of wastewater from hydraulic fracturing.

The OPA is the primary federal law for crude oil spill liability. The OPA contains numerous requirements relating to the prevention of and response to petroleum releases into regulated waters, including the requirement that operators of offshore facilities and certain onshore facilities near or crossing waterways must develop and maintain facility response contingency plans and maintain certain significant levels of financial assurance to cover potential environmental cleanup and restoration costs. The OPA subjects owners of facilities to strict, joint and several liability for all containment and cleanup costs and certain other damages arising from a release, including, but not limited to, the costs of responding to a release of crude oil into surface waters.

Noncompliance with the CWA, the SDWA, or the OPA may result in substantial administrative, civil and criminal penalties, as well as injunctive obligations, for the E&P operators of the acreage underlying Desert Peak’s mineral interests.

Air Emissions

The CAA, and comparable state laws and regulations, regulate emissions of various air pollutants through the issuance of permits and the imposition of other requirements. The EPA has developed, and continues to develop, stringent regulations governing emissions of air pollutants at specified sources. New facilities may be required to obtain permits before work can begin, and existing facilities may be required to obtain additional permits and incur capital costs in order to remain in compliance. For example, in June 2016, the EPA established criteria for aggregating multiple small surface sites into a single source for air quality permitting purposes, which could cause small facilities, on an aggregate basis, to be deemed a major source subject to more stringent air permitting processes and requirements. These laws and regulations may increase the costs of compliance for crude oil and natural gas producers and impact production of the acreage underlying Desert Peak’s mineral and royalty interests. In addition federal and state regulatory agencies can impose administrative, civil and criminal penalties for non-compliance with air permits or other requirements of the federal CAA and associated state laws and regulations. Moreover, obtaining or renewing permits has the potential to delay the development of crude oil and natural gas projects.

Climate Change

Climate change continues to attract considerable public and scientific attention. As a result, numerous proposals have been made and are likely to continue to be made at the international, national, regional and state levels of government to monitor and limit emissions of carbon dioxide, methane and other GHGs. These efforts have included consideration of cap-and-trade programs, carbon taxes, GHG reporting and tracking programs and regulations that directly limit GHG emissions from certain sources.

In the United States, no comprehensive climate change legislation has been implemented at the federal level. However, President Biden has highlighted addressing climate change as a priority of his administration and has issued several executive orders addressing climate change. Moreover, following the U.S. Supreme Court finding that GHG emissions constitute a pollutant under the CAA, the EPA has adopted regulations that, among other things, establish construction and operating permit reviews for GHG emissions from certain large stationary sources, require the monitoring and annual reporting of GHG emissions from certain petroleum and natural gas system sources in the United States, and together with the DOT, implementing GHG emissions limits on vehicles manufactured for operation in the United States. The regulation of methane from oil and gas facilities has been subject to uncertainty in recent years. In September 2020, the Trump Administration revised regulations

 

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initially promulgated in June 2016 to rescind certain methane standards and remove the transmission and storage segments from the source category for certain regulations. However, subsequently, the U.S. Congress approved, and President Biden signed into law, a resolution under the Congressional Review Act to repeal the September 2020 revisions to the methane standards, effectively reinstating the prior standards. Additionally, in November 2021, the EPA issued a proposed rule that, if finalized, would establish OOOO(b) new source and OOOO(c) first-time existing source standards of performance for methane and volatile organic compound emissions for oil and gas facilities. Operators of affected facilities will have to comply with specific standards of performance to include leak detection using optical gas imaging and subsequent repair requirement, and reduction of emissions by 95% through capture and control systems. The EPA plans to issue a supplemental proposal in 2022 containing additional requirements not included in the November 2021 proposed rule and anticipates the issuance of a final rule by the end of the year. We cannot predict the scope of any final methane regulatory requirements or the cost to comply with such requirements. However, given the long-term trend toward increasing regulation, future federal GHG regulations of the oil and gas industry remain a significant possibility.

Separately, various states and groups of states have adopted or are considering adopting legislation, regulation or other regulatory initiatives that are focused on such areas as GHG cap and trade programs, carbon taxes, reporting and tracking programs, and restriction of emissions. For example, New Mexico has adopted regulations to restrict the venting or flaring of methane from both upstream and midstream operations. At the international level, the United Nations-sponsored “Paris Agreement” requires member states to submit non-binding, individually-determined reduction goals known as Nationally Determined Contributions every five years after 2020. President Biden has recommitted the United States to the Paris Agreement and, in April 2021, announced a goal of reducing the United States’ emissions by 50-52% below 2005 levels by 2030. Additionally, at COP26 in Glasgow in November 2021, the United States and the European Union jointly announced the launch of a Global Methane Pledge, an initiative committing to a collective goal of reducing global methane emissions by at least 30 percent from 2020 levels by 2030, including “all feasible reductions” in the energy sector. The full impact of these actions cannot be predicted at this time.

Governmental, scientific, and public concern over the threat of climate change arising from GHG emissions has resulted in increasing political risks in the United States, including climate change related pledges made by certain candidates now in public office. On January 27, 2021, President Biden issued an Executive Order that calls for substantial action on climate change, including, among other things, the increased use of zero-emission vehicles by the federal government, the elimination of subsidies provided to the fossil fuel industry, and increased emphasis on climate-related risks across government agencies and economic sectors. The Biden Administration has also called for restrictions on leasing on federal land, including the Department of the Interior’s publication of a report recommending various changes to the federal leasing program, though many such changes would require Congressional action. Substantially all of Desert Peak’s interests are located on private lands, but it cannot predict the full impact of these developments or whether the Biden Administration may pursue further restrictions. Other actions that could be pursued by the Biden Administration may include the imposition of more restrictive requirements for the establishment of pipeline infrastructure or the permitting of LNG export facilities, as well as more restrictive GHG emission limitations for oil and gas facilities. Litigation risks are also increasing as a number of entities have sought to bring suit against various oil and natural gas companies in state or federal court, alleging among other things that such companies created public nuisances by producing fuels that contributed to climate change or alleging that the companies have been aware of the adverse effects of climate change for some time but defrauded their investors or customers by failing to adequately disclose those impacts.

There are also increasing financial risks for fossil fuel producers as shareholders currently invested in fossil-fuel energy companies may elect in the future to shift some or all of their investments into non-fossil fuel related sectors. Institutional lenders who provide financing to fossil fuel energy companies also have become more attentive to sustainable lending practices and some of them may elect not to provide funding for fossil fuel energy companies. For example, at COP26, GFANZ announced that commitments from over 450 firms across 45 countries had resulted in over $130 trillion in capital committed to net zero goals. The various sub-alliances of

 

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GFANZ generally require participants to set short-term, sector-specific targets to transition their financing, investing, and/or underwriting activities to net zero emissions by 2050. There is also a risk that financial institutions will be required to adopt policies that have the effect of reducing the funding provided to the fossil fuel sector. In late 2021, the Federal Reserve announced that it had joined the Network for Greening the Financial System, a consortium of financial regulators focused on addressing climate-related risks in the financial sector. Subsequently, in November 2021, the Federal Reserve issued a statement in support of the efforts of the Network for Greening the Financial System to identify key issues and potential solutions for the climate-related challenges most relevant to central banks and supervisory authorities. Limitation of investments in and financing for fossil fuel energy companies could result in the restriction, delay or cancellation of drilling programs or development or production activities. Additionally, the SEC announced its intention to promulgate rules requiring climate disclosures. Although the form and substance of these requirements is not yet known, this may result in additional costs to comply with any such disclosure requirements.

The adoption and implementation of new or more stringent international, federal or state legislation, regulations or other regulatory initiatives that impose more stringent standards for GHG emissions from the oil and natural gas sector or otherwise restrict the areas in which this sector may produce oil and natural gas or generate the GHG emissions could result in increased costs of compliance or costs of consuming, and thereby reduce demand for oil and natural gas, which could reduce the profitability of Desert Peak’s interests. Additionally, political, litigation and financial risks may result in Desert Peak’s oil and natural gas operators restricting or cancelling production activities, incurring liability for infrastructure damages as a result of climatic changes, or impairing their ability to continue to operate in an economic manner, which also could reduce the profitability of Desert Peak’s interests. One or more of these developments could have a material adverse effect on Desert Peak’s business, financial condition and results of operation.

Climate change may also result in various physical risks, such as the increased frequency or intensity of extreme weather events or changes in meteorological and hydrological patterns, that could adversely impact our operations, as well as those of our operators and their supply chains. Such physical risks may result in damage to operators’ facilities or otherwise adversely impact their operations, such as if they become subject to water use curtailments in response to drought, or demand for their products, such as to the extent warmer winters reduce the demand for energy for heating purposes. Extreme weather conditions can interfere with production and increase costs and damage resulting from extreme weather may not be fully insured. However, at this time, Desert Peak is unable to determine the extent to which climate change may lead to increased storm or weather hazards affecting its business.

Regulation of Hydraulic Fracturing

Hydraulic fracturing is an important and common practice that is used to stimulate production of hydrocarbons from tight formations. The process involves the injection of water, sand and chemicals under pressure into formations to fracture the surrounding rock and stimulate production. Hydraulic fracturing operations have historically been overseen by state regulators as part of their crude oil and natural gas regulatory programs. However, several agencies have asserted regulatory authority over certain aspects of the process. For example, in August 2012, the EPA finalized regulations under the federal CAA that establish new air emission controls for crude oil and natural gas production and natural gas processing operations. Federal regulation of methane emissions from the oil and gas sector has been subject to substantial controversy in recent years. For more information, see Desert Peak’s risk factor titled “Desert Peak’s operations, and those of its E&P operators, are subject to a series of risks arising from climate change.”

In addition, governments have studied the environmental aspects of hydraulic fracturing practices. These studies, depending on their degree of pursuit and whether any meaningful results are obtained, could spur initiatives to further regulate hydraulic fracturing under the SDWA or other regulatory authorities. For example, in December 2016, the EPA issued its final report on a study it had conducted over several years regarding the effects of hydraulic fracturing on drinking water sources. The final report, concluded that “water cycle” activities associated with hydraulic fracturing may impact drinking water under certain limited circumstances.

 

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Several states have adopted, or are considering adopting, regulations that could restrict or prohibit hydraulic fracturing in certain circumstances and/or require the disclosure of the composition of hydraulic fracturing fluids. For example, the Texas Railroad Commission has previously issued a “well integrity rule,” which updates the requirements for drilling, putting pipe down, and cementing wells. The rule also includes new testing and reporting requirements, such as: (i) the requirement to submit cementing reports after well completion or after cessation of drilling, whichever is later; and (ii) the imposition of additional testing on wells less than 1,000 feet below usable groundwater. The well integrity rule took effect in January 2014. Local governments also may seek to adopt ordinances within their jurisdictions regulating the time, place and manner of drilling activities in general or hydraulic fracturing activities in particular or prohibit the performance of well drilling in general or hydraulic fracturing in particular.

State and federal regulatory agencies recently have focused on a possible connection between the hydraulic fracturing related activities, particularly the disposal of produced water in underground injection wells, and the increased occurrence of seismic activity. When caused by human activity, such events are called induced seismicity. In some instances, operators of injection wells in the vicinity of seismic events have been ordered to reduce injection volumes or suspend operations. Some state regulatory agencies, including those in Colorado, Ohio, Oklahoma and Texas, have modified their regulations to account for induced seismicity. For example, in October 2014, the Texas Railroad Commission published a new rule governing permitting or re-permitting of disposal wells that would require, among other things, the submission of information on seismic events occurring within a specified radius of the disposal well location, as well as logs, geologic cross sections and structure maps relating to the disposal area in question. If the permittee or an applicant of a disposal well permit fails to demonstrate that the produced water or other fluids are confined to the disposal zone or if scientific data indicates such a disposal well is likely to be or determined to be contributing to seismic activity, then the agency may deny, modify, suspend or terminate the permit application or existing operating permit for that well. The Texas Railroad Commission has used this authority to deny permits for waste disposal wells. In some instances, regulators may also order that disposal wells be shut in. In late 2021, the Texas Railroad Commission issued a notice to operators of disposal wells in the Midland area, to reduce saltwater disposal well actions and provide certain data to the commission. Separately, in November 2021, New Mexico implemented protocols requiring operators to take various actions within a specified proximity of certain seismic activity, including a requirement to limit injection rates if a seismic event is of a certain magnitude. As a result of these developments, Desert Peak’s operators may be required to curtail operations or adjust development plans, which may adversely impact Desert Peak’s business.

The USGS has identified six states with the most significant hazards from induced seismicity, including New Mexico, Oklahoma and Texas. In addition, a number of lawsuits have been filed, most recently in Oklahoma, alleging that disposal well operations have caused damage to neighboring properties or otherwise violated state and federal rules regulating waste disposal. These developments could result in additional regulation and restrictions on the use of injection wells and hydraulic fracturing. Such regulations and restrictions could cause delays and impose additional costs and restrictions on the E&P operators of Desert Peak’s properties and on their waste disposal activities.

If new laws or regulations that significantly restrict hydraulic fracturing and related activities are adopted, such laws could make it more difficult or costly to perform fracturing to stimulate production from tight formations. In addition, if hydraulic fracturing is further regulated at the federal or state level, fracturing activities could become subject to additional permitting and financial assurance requirements, more stringent construction specifications, increased monitoring, reporting and recordkeeping obligations, plugging and abandonment requirements and also to attendant permitting delays and potential increases in costs. Such legislative changes could cause E&P operators to incur substantial compliance costs, and compliance or the consequences of any failure to comply by E&P operators could have a material adverse effect on Desert Peak’s financial condition and results of operations. At this time, it is not possible to estimate the impact on Desert Peak’s business of newly enacted or potential federal or state legislation governing hydraulic fracturing.

 

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Endangered Species Act

The ESA restricts activities that may affect endangered and threatened species or their habitats. The designation of previously unidentified endangered or threatened species could cause E&P operators to incur additional costs or become subject to operating delays, restrictions or bans in the affected areas. Recently, there have been renewed calls to review protections currently in place for the dunes sagebrush lizard, whose habitat includes parts of the Permian Basin, and to reconsider listing the species under the ESA. For example, in October 2019 environmental groups filed a lawsuit against the FWS seeking to compel the agency to list the species under the ESA, and in July 2020, FWS agreed to initiate a 12-month review to determine whether listing the species was warranted, which determination remains outstanding. Additionally, in June 2021, the FWS proposed to list two distinct population sections of the Lesser Prairie Chicken, including one in portions of the Permian Basin, under the ESA. To the extent species are listed under the ESA or similar state laws, or previously unprotected species are designated as threatened or endangered in areas where Desert Peak’s properties are located, operations on those properties could incur increased costs arising from species protection measures and face delays or limitations with respect to production activities thereon.

Employee Health and Safety

Operations on Desert Peak’s properties are subject to a number of federal and state laws and regulations, including the federal Occupational Safety and Health Act (“OSHA”) and comparable state statutes, whose purpose is to protect the health and safety of workers. In addition, the OSHA hazard communication standard, the EPA community right-to-know regulations under Title III of the federal Superfund Amendment and Reauthorization Act, and comparable state statutes require that information be maintained concerning hazardous materials used or produced in operations and that this information be provided to employees, state and local government authorities and citizens.

Other Regulation of the Crude Oil and Natural Gas Industry

The crude oil and natural gas industry is extensively regulated by numerous federal, state and local authorities. Legislation affecting the crude oil and natural gas industry is under constant review for amendment or expansion, frequently increasing the regulatory burden. Also, numerous departments and agencies, both federal and state, are authorized by statute to issue rules and regulations that are binding on the crude oil and natural gas industry and its individual members, some of which carry substantial penalties for failure to comply. Although the regulatory burden on the crude oil and natural gas industry increases the cost of doing business, these burdens generally do not affect us any differently or to any greater or lesser extent than they affect other companies in the industry with similar types, quantities and locations of production.

The availability, terms and conditions and cost of transportation significantly affect sales of crude oil and natural gas. The interstate transportation of crude oil and natural gas and the sale for resale of natural gas is subject to federal regulation, including regulation of the terms, conditions and rates for interstate transportation, storage and various other matters, primarily by the Federal Energy Regulatory Commission (“FERC”). Federal and state regulations govern the price and terms for access to crude oil and natural gas pipeline transportation. FERC’s regulations for interstate crude oil and natural gas transmission in some circumstances may also affect the intrastate transportation of crude oil and natural gas.

Desert Peak cannot predict whether new legislation to regulate crude oil and natural gas might be proposed, what proposals, if any, might actually be enacted by the U.S. Congress or the various state legislatures, and what effect, if any, the proposals might have on its operations. Sales of crude oil, condensate and NGLs are not currently regulated and are made at market prices.

Drilling and Production

The operations of the E&P operators of Desert Peak’s properties are subject to various types of regulation at the federal, state and local level. These types of regulation include requiring permits for the drilling of wells,

 

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drilling bonds and reports concerning operations. The state, and some counties and municipalities, in which Desert Peak operates also regulate one or more of the following:

 

   

the location of wells;

 

   

the method of drilling and casing wells;

 

   

the timing of construction or drilling activities, including seasonal wildlife closures;

 

   

the rates of production or “allowables”;

 

   

the surface use and restoration of properties upon which wells are drilled;

 

   

the plugging and abandoning of wells;

 

   

and notice to, and consultation with, surface owners and other third parties.

State laws regulate the size and shape of drilling and spacing units or proration units governing the pooling of crude oil and natural gas properties. Some states allow forced pooling or integration of tracts to facilitate exploration while other states rely on voluntary pooling of lands and leases. In some instances, forced pooling or unitization may be implemented by third parties and may reduce Desert Peak’s interest in the unitized properties. In addition, state conservation laws establish maximum rates of production from crude oil and natural gas wells, generally prohibit the venting or flaring of natural gas and impose requirements regarding the ratability of production. These laws and regulations may limit the amount of crude oil and natural gas that the E&P operators of Desert Peak’s properties can produce from Desert Peak’s wells or limit the number of wells or the locations at which E&P operators can drill. Moreover, each state generally imposes a production or severance tax with respect to the production and sale of crude oil, natural gas and NGLs within its jurisdiction. States do not regulate wellhead prices or engage in other similar direct regulation, but Desert Peak cannot assure you that they will not do so in the future. The effect of such future regulations may be to limit the amounts of crude oil and natural gas that may be produced from Desert Peak’s wells, negatively affect the economics of production from these wells or to limit the number of locations E&P operators can drill.

Federal, state and local regulations provide detailed requirements for the abandonment of wells, closure or decommissioning of production facilities and pipelines and for site restoration in areas where the E&P operators of Desert Peak’s properties operate. The U.S. Army Corps of Engineers and many other state and local authorities also have regulations for plugging and abandonment, decommissioning and site restoration. Although the U.S. Army Corps of Engineers does not require bonds or other financial assurances, some state agencies and municipalities do have such requirements.

Natural Gas Sales and Transportation

FERC has jurisdiction over the transportation and sale for resale of natural gas in interstate commerce by natural gas companies under the Natural Gas Act of 1938 (“NGA”) and the Natural Gas Policy Act of 1978. Since 1978, various federal laws have been enacted which have resulted in the complete removal of all price and non-price controls for sales of domestic natural gas sold in “first sales.”

Under the Energy Policy Act of 2005, FERC has substantial enforcement authority to prohibit the manipulation of natural gas markets and enforce its rules and orders, including the ability to assess substantial civil penalties. FERC also regulates interstate natural gas transportation rates and service conditions and establishes the terms under which the E&P operators of Desert Peak’s properties may use interstate natural gas pipeline capacity, as well as the revenues such E&P operators receive for release of natural gas pipeline capacity. Interstate pipeline companies are required to provide nondiscriminatory transportation services to producers, marketers and other shippers, regardless of whether such shippers are affiliated with an interstate pipeline company. FERC’s initiatives have led to the development of a competitive, open access market for natural gas

 

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purchases and sales that permits all purchasers of natural gas to buy gas directly from third-party sellers other than pipelines.

Gathering service, which occurs upstream of jurisdictional transmission services, is regulated by the states onshore and in state waters. Section 1(b) of the NGA exempts natural gas gathering facilities from regulation by FERC under the NGA. FERC has in the past reclassified certain jurisdictional transmission facilities as non-jurisdictional gathering facilities, which may increase the E&P operators’ costs of transporting gas to point-of-sale locations. This may, in turn, affect the costs of marketing natural gas that the E&P operators of Desert Peak’s properties produce.

Historically, the natural gas industry was more heavily regulated; therefore, Desert Peak cannot guarantee that the regulatory approach currently pursued by FERC and the U.S. Congress will continue indefinitely into the future nor can Desert Peak determine what effect, if any, future regulatory changes might have on its natural gas related activities.

Crude Oil Sales and Transportation

Crude oil sales are affected by the availability, terms and cost of transportation. The transportation of crude oil in common carrier pipelines is also subject to rate regulation. FERC regulates interstate crude oil pipeline transportation rates under the Interstate Commerce Act and intrastate crude oil pipeline transportation rates are subject to regulation by state regulatory commissions. The basis for intrastate crude oil pipeline regulation, and the degree of regulatory oversight and scrutiny given to intrastate crude oil pipeline rates, varies from state to state. Insofar as effective interstate and intrastate rates are equally applicable to all comparable shippers, Desert Peak believes that the regulation of crude oil transportation rates will not affect its operations in any materially different way than such regulation will affect the operations of its competitors.

Further, interstate and intrastate common carrier crude oil pipelines must provide service on a non-discriminatory basis. Under this open access standard, common carriers must offer service to all similarly situated shippers requesting service on the same terms and under the same rates. When crude oil pipelines operate at full capacity, access is governed by prorationing provisions set forth in the pipelines’ published tariffs. Accordingly, Desert Peak believes that access to crude oil pipeline transportation services by E&P operators of Desert Peak’s properties will not materially differ from Desert Peak’s competitors’ access to crude oil pipeline transportation services.

State Regulation

Texas regulates the drilling for, and the production, gathering and sale of, crude oil and natural gas, including imposing severance taxes and requirements for obtaining drilling permits. Texas currently imposes a 4.6% severance tax on the market value of crude oil production and a 7.5% severance tax on the market value of natural gas production. States also regulate the method of developing new fields, the spacing and operation of wells and the prevention of waste of crude oil and natural gas resources.

States may regulate rates of production and may establish maximum daily production allowables from crude oil and natural gas wells based on market demand or resource conservation, or both. States do not regulate wellhead prices or engage in other similar direct economic regulation, but Desert Peak cannot assure you that they will not do so in the future. Should direct economic regulation or regulation of wellhead prices by the states increase, this could limit the amount of crude oil and natural gas that may be produced from wells on Desert Peak’s properties and the number of wells or locations the E&P operators of Desert Peak’s properties can drill.

The petroleum industry is also subject to compliance with various other federal, state and local regulations and laws. Some of those laws relate to resource conservation and equal employment opportunity. Desert Peak does not believe that compliance with these laws will have a material adverse effect on its business.

 

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Title to Properties

Prior to completing an acquisition of mineral and royalty interests, Desert Peak performs a title review on each tract to be acquired. Desert Peak’s title review is meant to confirm the quantum of mineral and royalty interest owned by a prospective seller, the property’s lease status and royalty amount as well as encumbrances or other related burdens. As a result, title examinations have been obtained on a significant portion of Desert Peak’s properties.

In addition to Desert Peak’s initial title work, E&P operators often will conduct a thorough title examination prior to leasing and/or drilling a well. Should an E&P operator’s title work uncover any further title defects, either Desert Peak or the E&P operator will perform curative work with respect to such defects. An E&P operator generally will not commence drilling operations on a property until any material title defects on such property have been cured.

Desert Peak believes that the title to its assets is satisfactory in all material respects. Although title to these properties is in some cases subject to encumbrances, such as customary interests generally retained in connection with the acquisition of crude oil and gas interests, non-participating royalty interests and other burdens, easements, restrictions or minor encumbrances customary in the crude oil and natural gas industry, Desert Peak believes that none of these encumbrances will materially detract from the value of these properties or from its interest in these properties.

Competition

The crude oil and natural gas business is highly competitive; Desert Peak primarily competes with companies for the acquisition of mineral and royalty interests and acquisition of minerals and crude oil and natural gas leases. Many of Desert Peak’s competitors not only own and acquire mineral and royalty interests but also explore for and produce crude oil and natural gas and, in some cases, carry on midstream and refining operations and market petroleum and other products on a regional, national or worldwide basis. By engaging in such other activities, Desert Peak’s competitors may be able to develop or obtain information that is superior to the information that is available to us. In addition, certain of Desert Peak’s competitors may possess financial or other resources substantially larger than Desert Peak possesses. Desert Peak’s ability to acquire additional minerals and properties and to discover reserves in the future will be dependent upon its ability to evaluate and select suitable properties and to consummate transactions in a highly competitive environment.

In addition, crude oil and natural gas products compete with other forms of energy available to customers, primarily based on price. These alternate forms of energy include electricity, coal, and fuel oils. Changes in the availability or price of crude oil and natural gas or other forms of energy, as well as business conditions, conservation, legislation, regulations, and the ability to convert to alternate fuels and other forms of energy may affect the demand for crude oil and natural gas.

Seasonality of Business

Weather conditions affect the demand for, and prices of, natural gas and can also delay drilling activities, disrupting Desert Peak’s overall business plans. Additionally, some of the areas in which Desert Peak’s properties are located are adversely affected by seasonal weather conditions, primarily in the winter and spring. During periods of heavy snow, ice or rain, Desert Peak’s E&P operators may be unable to move their equipment between locations, thereby reducing their ability to operate Desert Peak’s wells, reducing the amount of crude oil and natural gas produced from the wells on Desert Peak’s properties during such times. Additionally, extended drought conditions in the areas in which Desert Peak’s properties are located could impact its E&P operators’ ability to source sufficient water or increase the cost for such water. Furthermore, demand for natural gas is typically higher during the winter, resulting in higher natural gas prices for Desert Peak’s natural gas production during its first and fourth quarters. Certain natural gas users utilize natural gas storage facilities and purchase

 

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some of their anticipated winter requirements during the summer, which can lessen seasonal demand fluctuations. Seasonal weather conditions can limit drilling and producing activities and other crude oil and natural gas operations in a portion of Desert Peak’s operating areas. Due to these seasonal fluctuations, Desert Peak’s results of operations for individual quarterly periods may not be indicative of the results that it may realize on an annual basis.

Employees

Desert Peak and its predecessor do not have any employees. As of December 31, 2021, an affiliate of Desert Peak’s predecessor employed approximately 26 full-time equivalent individuals who provided direct support to Desert Peak’s operations pursuant to a management services arrangement. None of these employees are covered by collective bargaining agreements. Immediately after the Closing, Desert Peak expects to employ approximately 30 individuals, none of which are expected to be covered by collective bargaining agreements.

Legal Proceedings

Desert Peak is party to lawsuits arising in the ordinary course of its business. Desert Peak cannot predict the outcome of any such lawsuits with certainty, but Desert Peak’s management believes it is remote that pending or threatened legal matters will have a material adverse impact on its financial condition.

 

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