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): February 7, 2017

 

 

PARSLEY ENERGY, INC.

(Exact Name of Registrant as Specified in its Charter)

 

 

 

Delaware   001-36463   46-4314192

(State or Other Jurisdiction

of Incorporation)

 

(Commission

File Number)

 

(IRS Employer

Identification Number)

303 Colorado Street, Suite 3000

Austin, Texas 78701

(Address of Principal Executive Offices)

(Zip Code)

(737) 704-2300

(Registrant’s Telephone Number, Including Area Code)

 

 

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))

 

 

 


Item 1.01 Entry into a Material Definitive Agreement.

Double Eagle Contribution Agreement

On February 7, 2017, Parsley Energy, Inc. (the “Company”) entered into a Contribution Agreement (the “Contribution Agreement”) by and among Parsley Energy, LLC (“Parsley LLC”), the Company, Double Eagle Energy Permian Operating LLC (“DE Operating”), Double Eagle Energy Permian LLC (“DE Permian”) and Double Eagle Energy Permian Member LLC (together with DE Operating and DE Permian, “Double Eagle”), which provides for the contribution by Double Eagle of all of its interests in Double Eagle Lone Star LLC, DE Operating LLC, and Veritas Energy Partners, LLC, as well as certain related transactions with an affiliate of Double Eagle. As a result, the Company expects to acquire (the “Acquisition”) approximately 167,000 gross (71,000 net) acres located in the Midland Basin and approximately 7,300 gross (3,300 net) associated horizontal drilling locations for an aggregate purchase price of approximately $2.8 billion, subject to certain purchase price adjustments set forth in the Contribution Agreement. A copy of the news release related to the Acquisition is attached hereto as Exhibit 99.1 and incorporated herein by reference.

The aggregate purchase price for the Acquisition will consist of (i) approximately $1.4 billion in cash and (ii) approximately 39.4 million units in Parsley LLC (“PE Units”) and a corresponding approximately 39.4 million shares of the Company’s Class B common stock. Upon the terms and conditions contained in the Contribution Agreement, concurrently with the closing of the Acquisition, Parsley LLC will amend its limited liability company agreement to, among other things, admit DE Operating and its designees as members of Parsley LLC. Upon the expiration of a 90-day lock-up period following the consummation of the Acquisition, each PE Unit, together with a corresponding share of the Company’s Class B common stock, will be exchangeable, at the option of the holder, for one share of the Company’s Class A common stock, or, if either the Company or Parsley LLC so elects, cash.

In connection with the closing of the Acquisition, the Company intends to enter into a registration rights and lock-up agreement (the “Registration Rights Agreement”) with DE Operating and its equity holders containing provisions by which the Company will agree to, among other things and subject to certain restrictions, file an automatically effective registration statement with the Securities and Exchange Commission on Form S-3 providing for the registration of the shares of the Company’s Class A common stock issuable upon exchange of the PE Units (and corresponding shares of the Company’s Class B common stock) to be issued as consideration to DE Operating and to conduct certain underwritten offerings thereof.

The Contribution Agreement contains customary representations and warranties, covenants and indemnification provisions and has an effective date of January 1, 2017. The Company and Double Eagle expect to close the Acquisition on or before April 20, 2017, subject to the satisfaction of customary closing conditions.

The Contribution Agreement is filed as Exhibit 2.1 to this Current Report on Form 8-K, and the foregoing summary description of the Contribution Agreement is qualified in its entirety by reference to such exhibit, which is incorporated herein by reference. The Contribution Agreement is filed herewith to provide investors with information regarding its terms. It is not intended to provide any other factual information about the parties. In particular, the assertions embodied in the representations and warranties contained in the Contribution Agreement were made as of the date of the Contribution Agreement only and are in certain instances qualified by information in confidential disclosure schedules provided by the parties to each other in connection with the signing of the Contribution Agreement. These disclosure schedules contain information that modifies, qualifies and creates exceptions to the representations and warranties set forth in the Contribution Agreement. Moreover, certain representations and warranties in the Contribution Agreement may have been used for the purpose of allocating risk between the parties rather than establishing matters of fact. Accordingly, you should not rely on the representations and warranties in the Contribution Agreement as characterizations of the actual statements of fact about the parties.

 

Item 2.02 Results of Operations and Financial Condition.

On February 7, 2017, the Company announced, among other things, certain results of operations and financial and operational guidance. A copy of the Company’s news release is attached hereto as Exhibit 99.1 and incorporated herein by reference.

 

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The information in this Item 2.02 (including the exhibit) shall not be deemed to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), or otherwise subject to the liabilities of that section, and is not incorporated by reference into any filing under the Securities Act of 1933, as amended (the “Securities Act”), or the Exchange Act.

 

Item 3.02 Unregistered Sales of Equity Securities.

Pursuant to the Contribution Agreement, Parsley LLC and the Company will issue approximately 39.4 million shares of PE Units and a corresponding number of shares of Class B common stock, respectively, as consideration for the Acquisition, subject to the terms and adjustments set forth in the Contribution Agreement. Each PE Unit, together with a corresponding share of Class B common stock, will be exchangeable, at the option of the holder and after the lock-up period set forth in the Registration Rights Agreement, for one share of Class A common stock, or, if either the Company or Parsley LLC so elects, cash. The issuance of such securities will be made in reliance upon an exemption from registration provided under Section 4(a)(2) of the Securities Act.

The Acquisition is expected to close on or before April 20, 2017, subject to the satisfaction of customary closing conditions.

 

Item 7.01 Regulation FD Disclosure.

Offering of Class A Common Stock

On February 7, 2017, the Company issued a news release announcing the commencement of an underwritten public offering of 36,000,000 shares of its Class A common stock (the “Equity Offering”). The Company expects to grant the underwriters a 30-day option to purchase up to an additional 5,400,000 shares of Class A common stock. A copy of the news release is attached hereto as Exhibit 99.2 and incorporated herein by reference.

Offering of Senior Notes

On February 7, 2017, Parsley LLC issued a press release announcing that, subject to market and other conditions, it, and its wholly owned subsidiary, Parsley Finance Corp., intend to commence a private placement of $350 million in aggregate principal amount of senior unsecured notes due 2025 (the “Notes Offering”). A copy of the news release is attached hereto as Exhibit 99.3 and incorporated herein by reference.

The information in this Item 7.01 (including the exhibits) 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, and is not incorporated by reference into any filing under the Securities Act or the Exchange Act.

 

Item 8.01 Other Events.

(i) In connection with the Equity Offering, the Company provided the additional risk factors set forth below in the disclosures provided to investors. Substantially similar versions of certain of such risk factors were provided to investors in the Notes Offering. Capitalized terms used but not defined below have the meaning given such terms in the prospectus supplement related to the Equity Offering.

We may not consummate the Double Eagle Acquisition or the Concurrent Notes Offering, and this offering is not conditioned on the consummation of the Double Eagle Acquisition or the Concurrent Notes Offering.

We intend to use the net proceeds from this offering, along with the net proceeds from the Concurrent Notes Offering, to fund the cash portion of the purchase price for the Double Eagle Acquisition, as described under “Summary—Recent Developments.” However, we may not consummate the Double Eagle Acquisition, which is subject to the satisfaction of customary closing conditions. There can be no assurance that such conditions will be satisfied or that the Double Eagle Acquisition will be consummated. Further, we may not consummate the Concurrent Notes Offering, which is subject to market conditions and other factors.

This offering is not conditioned on the consummation of the Double Eagle Acquisition or the Concurrent Notes Offering. Therefore, upon the closing of this offering, you will become a holder of our Class A common stock regardless of whether the Double Eagle Acquisition and the Concurrent Notes Offering are consummated, delayed

 

3


or terminated. If the Double Eagle Acquisition or the Concurrent Notes Offering is delayed or terminated, the price of our Class A common stock may decline to the extent that the current market price of our Class A common stock reflects a market assumption that the Double Eagle Acquisition and the Concurrent Notes Offering will be consummated on the terms described herein.

If the Double Eagle Acquisition is not consummated, our management will have broad discretion in the application of the net proceeds from this offering and could apply the proceeds in ways that you or other stockholders may not approve. In addition, if the Concurrent Notes Offering is not consummated, our management will have broad discretion in the source of funds for the remaining cash portion of the purchase price for the Double Eagle Acquisition, and could draw upon such other sources of funds in ways that you or other stockholders may not approve. In either event, the market price of our Class A common stock could be adversely affected.

If the Double Eagle Acquisition is consummated, we may be unable to successfully integrate Double Eagle’s operations or to realize anticipated cost savings, revenues or other benefits of the Double Eagle Acquisition.

Our ability to achieve the anticipated benefits of the Double Eagle Acquisition, if consummated, will depend in part upon whether we can integrate Double Eagle’s assets and operations into our existing business in an efficient and effective manner. We may not be able to accomplish this integration process successfully. The successful Double Eagle Acquisition of producing properties, including those acquired from Double Eagle, requires an assessment of several factors, including:

 

    recoverable reserves;

 

    future natural gas and oil prices and their appropriate differentials;

 

    availability and cost of transportation of production to markets;

 

    availability and cost of drilling equipment and of skilled personnel;

 

    development and operating costs and potential environmental and other liabilities; and

 

    regulatory, permitting and similar matters.

The accuracy of these assessments is inherently uncertain. In connection with these assessments, we have performed, and will continue to perform, a review of the subject properties, including properties that are subject to certain customary acreage swaps in process, that we believe to be generally consistent with industry practices. Our review may not reveal all existing or potential problems or permit us to become sufficiently familiar with the properties to fully assess their deficiencies and potential recoverable reserves. Inspections will not always be performed on every well, and environmental problems are not necessarily observable even when an inspection is undertaken. Even if problems are identified, the contractual protection provided with respect to all or a portion of the underlying deficiencies may prove ineffective or insufficient. The integration process may be subject to delays or changed circumstances, and we can give no assurance that the acquired properties will perform in accordance with our expectations or that our expectations with respect to integration or cost savings as a result of the Double Eagle Acquisition will materialize. Significant acquisitions, including the Double Eagle Acquisition, and other strategic transactions may involve other risks that may cause our business to suffer, including:

 

    diversion of our management’s attention to evaluating, negotiating and integrating significant acquisitions and strategic transactions;

 

    the challenge and cost of integrating acquired assets and operations with those of ours while carrying on our ongoing business; and

 

    the failure to realize the full benefit that we expect in estimated proved reserves, production volume, cost savings from operating synergies or other benefits anticipated from an acquisition, or to realize these benefits within the expected time frame.

 

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Our actual operating results, costs and activities could differ materially from the guidance we have released in connection with the Double Eagle Acquisition.

In connection with our announcement of the Double Eagle Acquisition, we have incorporated by reference into this prospectus supplement certain forecasted operating results, costs and activities, including, without limitation, our future expected production results, price realizations, operating expenses, capital expenditures and drilling activity. This forward-looking guidance represents our management’s estimates as of the date of this prospectus supplement, is based upon a number of assumptions that are inherently uncertain and is subject to numerous business, economic, competitive, financial and regulatory risks, including the risks described under “Risk Factors” and “Cautionary Statement Regarding Forward-Looking Statements” in this prospectus supplement and in our Annual Report on Form 10-K for the year ended December 31, 2015, which is incorporated herein by reference. Many of these risks and uncertainties are beyond our control, such as declines in commodity prices and the speculative nature of estimating natural gas, NGLs and oil reserves and in projecting future rates of production. If any of these risks and uncertainties actually occur or the assumptions underlying our guidance are incorrect, our actual operating results, costs and activities may be materially and adversely different from our guidance. In addition, investors should also recognize that the reliability of any guidance diminishes the farther in the future that the data is forecast. In light of the foregoing, investors are urged to put our guidance in context and not to place undue reliance upon it.

Our ability to use our net operating loss carryforwards may be limited.

We estimate that as of December 31, 2016, we had approximately $139.7 million of U.S. federal net operating loss carryforwards (“NOLs”), which begin to expire in 2034. Utilization of these NOLs depends on many factors, including our future income, which cannot be assured. In addition, Section 382 of the Internal Revenue Code of 1986, as amended (“Section 382”), generally imposes an annual limitation on the amount of NOLs that may be used to offset taxable income when a corporation has undergone an “ownership change” (as determined under Section 382). An ownership change generally occurs if one or more shareholders (or groups of shareholders) who are each deemed to own at least 5% of our stock change their ownership by more than 50 percentage points over their lowest ownership percentage within a rolling three-year period. In the event that an ownership change has occurred, or were to occur, utilization of our NOLs would be subject to an annual limitation under Section 382, determined by multiplying the value of our stock at the time of the ownership change by the applicable long-term tax-exempt rate as defined in Section 382, subject to certain adjustments. Any unused annual limitation may be carried over to later years. We cannot assure you that we will not undergo an ownership change in 2017 as a result of this offering, taking into account other changes in ownership of our stock occurring within the relevant three-year period described above. However, even if we did have an ownership change as a result of this offering, we do not believe that the resulting Section 382 annual limitation would prevent our utilization of our NOLs prior to their expiration. Future ownership changes or future regulatory changes could limit our ability to utilize our NOLs. To the extent we are not able to offset our future income with our NOLs, this would adversely affect our operating results and cash flows if we attain profitability.

In certain cases, payments under the Tax Receivable Agreement may be accelerated and/or significantly exceed the actual benefits, if any, we realize in respect of the tax attributes subject to the Tax Receivable Agreement.

If we elect to terminate the Tax Receivable Agreement early or it is terminated early due to certain mergers or other changes of control or due to a material breach of the Tax Receivable Agreement, we would be required to make an immediate payment equal to the present value of the anticipated future tax benefits subject to the Tax Receivable Agreement, for which we would be dependent on Parsley LLC. The calculation of anticipated future tax benefits will be based upon certain assumptions and deemed events as set forth in the Tax Receivable Agreement, including the assumption that we have sufficient taxable income to fully utilize such benefits and that any PE Units that the PE Unit Holders or their permitted transferees own on the termination date are deemed to be exchanged on the termination date. Any early termination payment may be made significantly in advance of the actual realization, if any, of such future benefits.

In these situations, our obligations under the Tax Receivable Agreement could have a substantial negative impact on our liquidity and could have the effect of delaying, deferring or preventing certain mergers, asset sales, other forms of business combinations or other changes of control due to the additional transaction costs a potential

 

5


acquirer may attribute to satisfying such obligations. For example, if the Tax Receivable Agreement were terminated at December 31, 2016, the estimated termination payment would be approximately $322.3 million (calculated using a discount rate equal to LIBOR, plus 300 basis points, applied against an undiscounted liability of $660.6 million). The foregoing number is merely an estimate and the actual payment could differ materially. There can be no assurance that we and Parsley LLC will be able to finance the obligations under the Tax Receivable Agreement.

Payments under the Tax Receivable Agreement will be based on the tax reporting positions that we will determine. The holders of rights under the Tax Receivable Agreement will not reimburse us for any payments previously made under the Tax Receivable Agreement if such basis increases or other benefits are subsequently disallowed, except that excess payments made to any such holder will be netted against payments otherwise to be made, if any, to such holder after our determination of such excess. As a result, in such circumstances, we could make payments that are greater than our actual cash tax savings, if any, and may not be able to recoup those payments, which could adversely affect our liquidity.

(ii) The Company is providing certain financial information with respect to the Acquisition. Included in this filing as Exhibits 99.4 and 99.5 are the audited consolidated financial statements of DE Permian (for the periods described in Item 9.01(a) below), the notes related thereto and the Reports of Independent Registered Public Accounting Firms, and included in this filing as Exhibit 99.6 are the unaudited condensed consolidated financial statements of DE Permian for the periods described in Item 9.01(a) below and the notes related thereto.

Included in this filing as Exhibit 99.7 is the unaudited pro forma condensed combined financial information described in Item 9.01(b) below.

Also included in this filing (i) as Exhibit 99.8 is the audit letter of independent petroleum engineer, Netherland, Sewell & Associates, Inc. and (ii) as Exhibits 99.9 and 99.10 are the reports of independent petroleum engineer, Cawley, Gillespie & Associates, Inc.

 

9.01 Financial Statements and Exhibits

 

(a) Financial Statements

 

    Audited consolidated financial statements of DE Permian as of December 31, 2014 and for the year then ended, and the related notes to the consolidated financial statements, attached as Exhibit 99.4 hereto.

 

    Audited consolidated financial statements of DE Permian as of December 31, 2015 and for the year then ended and the related notes to the consolidated financial statements, attached as Exhibit 99.5 hereto.

 

    Unaudited condensed consolidated financial statements of DE Permian comprised of the condensed consolidated balance sheet as of September 30, 2016, the related condensed consolidated statements of operations and cash flows for the nine months ended September 30, 2016 and 2015, the related condensed consolidated statements of changes in members’ equity for the nine months ended September 30, 2016 and the related notes to the unaudited condensed consolidated financial statements, attached as Exhibit 99.6 hereto.

 

(b) Pro Forma Financial Information

The following unaudited pro forma condensed combined financial information of the Company, giving effect to the Acquisition is included in Exhibit 99.7 hereto:

 

    Unaudited Pro Forma Condensed Combined Balance Sheet as of September 30, 2016.

 

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    Unaudited Pro Forma Condensed Combined Statements of Operations for the nine months ended September 30, 2016 and the year ended December 31, 2015.

 

    Notes to the Unaudited Pro Forma Condensed Combined Financial Statements.

(d) Exhibits.

 

Exhibit No.

  

Description

  2.1*    Contribution Agreement, dated as of February 7, 2017, by and between Parsley Energy, LLC, Parsley Energy, Inc., Double Eagle Energy Permian Operating LLC, Double Eagle Energy Permian LLC and Double Eagle Energy Permian Member LLC
23.1    Consent of Ernst & Young LLP
23.2    Consent of Weaver & Tidwell, L.L.P.
23.3    Consent of Netherland, Sewell & Associates, Inc.
23.4    Consent of Cawley, Gillespie & Associates, Inc.
99.1    News Release, dated February 7, 2017, titled “Parsley Energy Announces Consolidating Midland Basin Acquisition, Revises 2017 Capital Program And Operating Guidance, And Provides Updates On 4Q16 Operations, Year-End 2016 Reserves, And Recent Hedging Activity.”
99.2    News Release, dated February 7, 2017, titled “Parsley Energy Announces Public Offering of Class A Common Stock.”
99.3    News Release, dated February 7, 2017, titled “Parsley Energy, LLC Announces $350 Million Private Placement of Senior Unsecured Notes due 2025.”
99.4    Historical audited consolidated financial statements of Double Eagle Energy Permian LLC as of and for the year ended December 31, 2014
99.5    Historical audited consolidated financial statements of Double Eagle Energy Permian LLC as of and for the year ended December 31, 2015
99.6    Historical unaudited condensed consolidated financial statements of Double Eagle Energy Permian LLC as of and for the nine months ended September 30, 2016
99.7    Unaudited pro forma condensed combined financial information as of and for the nine months ended September 30, 2016 and the year ended December 31, 2015
99.8    Netherland, Sewell & Associates, Inc. Audit Letter at December 31, 2016 (Parsley Energy, Inc.)
99.9    Cawley, Gillespie & Associates, Inc. Summary of Reserves at December 31, 2015 (Double Eagle Energy Permian LLC)
99.10    Cawley, Gillespie & Associates, Inc. Summary of Reserves at December 31, 2014 (Double Eagle Energy Permian LLC)

 

* Schedules and similar attachments to the Contribution Agreement have been omitted pursuant to Item 601(b)(2) of Regulation S-K. The registrant will furnish a supplemental copy of any omitted schedule or similar attachment to the Securities and Exchange Commission upon request.

 

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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.

Date: February 7, 2017

 

PARSLEY ENERGY, INC.
By:  

/s/ Colin W. Roberts

Name:    Colin W. Roberts
Title:   Executive Vice President—General Counsel and Secretary


EXHIBIT INDEX

 

Exhibit No.

  

Description

  2.1*    Contribution Agreement, dated as of February 7, 2017, by and between Parsley Energy, LLC, Parsley Energy, Inc., Double Eagle Energy Permian Operating LLC, Double Eagle Energy Permian LLC and Double Eagle Energy Permian Member LLC
23.1    Consent of Ernst & Young LLP
23.2    Consent of Weaver & Tidwell, L.L.P.
23.3    Consent of Netherland, Sewell & Associates, Inc.
23.4    Consent of Cawley, Gillespie & Associates, Inc.
99.1    News Release, dated February 7, 2017, titled “Parsley Energy Announces Consolidating Midland Basin Acquisition, Revises 2017 Capital Program And Operating Guidance, And Provides Updates On 4Q16 Operations, Year-End 2016 Reserves, And Recent Hedging Activity.”
99.2    News Release, dated February 7, 2017, titled “Parsley Energy Announces Public Offering of Class A Common Stock.”
99.3    News Release, dated February 7, 2017, titled “Parsley Energy, LLC Announces $350 Million Private Placement of Senior Unsecured Notes due 2025.”
99.4    Historical audited consolidated financial statements of Double Eagle Energy Permian LLC as of and for the year ended December 31, 2014
99.5    Historical audited consolidated financial statements of Double Eagle Energy Permian LLC as of and for the year ended December 31, 2015
99.6    Historical unaudited condensed consolidated financial statements of Double Eagle Energy Permian LLC as of and for the nine months ended September 30, 2016
99.7    Unaudited pro forma condensed combined financial information as of and for the nine months ended September 30, 2016 and the year ended December 31, 2015
99.8    Netherland, Sewell & Associates, Inc. Audit Letter at December 31, 2016 (Parsley Energy, Inc.)
99.9    Cawley, Gillespie & Associates, Inc. Summary of Reserves at December 31, 2015 (Double Eagle Energy Permian LLC)
99.10    Cawley, Gillespie & Associates, Inc. Summary of Reserves at December 31, 2014 (Double Eagle Energy Permian LLC)

 

* Schedules and similar attachments to the Contribution Agreement have been omitted pursuant to Item 601(b)(2) of Regulation S-K. The registrant will furnish a supplemental copy of any omitted schedule or similar attachment to the Securities and Exchange Commission upon request.

Exhibit 2.1

Execution Version

CONTRIBUTION AGREEMENT

by and among

DOUBLE EAGLE ENERGY PERMIAN OPERATING LLC,

as Contributor,

DOUBLE EAGLE ENERGY PERMIAN LLC,

and

DOUBLE EAGLE ENERGY PERMIAN MEMBER LLC,

as Contributor Parent,

PARSLEY ENERGY, LLC,

as Acquiror,

PARSLEY ENERGY, INC.,

as Acquiror Parent,

and, solely for the purposes of Section  12.17 ,

DOUBLE EAGLE ENERGY HOLDCO LLC,

as Contributor Representative

Dated February 7, 2017


TABLE OF CONTENTS

 

         Page  
ARTICLE 1   
CONTRIBUTION   

1.1

 

Contribution

     1   

1.2

 

Certain Definitions

     2   

1.3

 

Excluded Assets

     12   
ARTICLE 2   
PURCHASE PRICE   

2.1

 

Purchase Price

     12   

2.2

 

Adjustments to Purchase Price

     14   

2.3

 

Withholding

     15   

ARTICLE 3

CERTAIN TITLE AND ENVIRONMENTAL MATTERS

  

  

3.1

 

Company Group’s Title

     15   

3.2

 

Definition of Defensible Title

     15   

3.3

 

Definition of Permitted Encumbrances

     17   

3.4

 

Allocated Values

     20   

3.5

 

Environmental Assessment; Environmental Defects

     21   

3.6

 

Notice of Title Defects, Environmental Defects and Title Benefits

     22   

3.7

 

Cure

     24   

3.8

 

Adjustment for Title Defects, Title Benefits and Environmental Defects

     25   

3.9

 

Calculation of Title Defect Amounts, Title Benefit Amounts and Environmental Defect Amounts

     27   

3.10

 

Dispute Resolution

     31   

3.11

 

Notice to Holders of Consents and Preferential Purchase Rights

     32   

3.12

 

Preferential Purchase Rights

     32   

3.13

 

Limitations on Applicability

     33   
ARTICLE 4   
REPRESENTATIONS AND WARRANTIES OF CONTRIBUTOR PARTIES   

4.1

 

Contributor; No Conflicts

     33   

4.2

 

Litigation

     35   

4.3

 

Taxes

     35   

4.4

 

Compliance with Laws

     36   

4.5

 

Contracts

     36   

4.6

 

Payments for Production; Imbalances

     37   

4.7

 

Consents, Preferential Purchase Rights, Tag-Along Rights and Drag-Along Rights

     37   

4.8

 

Liability for Brokers’ Fees

     37   

4.9

 

Wells and Equipment

     37   

4.10

 

Non-Consent Operations

     38   

4.11

 

Outstanding Capital Commitments

     38   

4.12

 

Environmental

     39   

 

-i-


TABLE OF CONTENTS

(continued)

 

         Page  

4.13

 

Hedging Transactions

     40   

4.14

 

Absence of Certain Changes

     40   

4.15

 

Records and Information

     40   

4.16

 

Lease Payments

     40   

4.17

 

Bonds and Letters of Credit

     41   

4.18

 

Insurance

     41   

4.19

 

Special Warranty of Title

     41   

4.20

 

Investment Intent

     41   

4.21

 

[Reserved]

     42   

4.22

 

Company Group

     42   

4.23

 

Capitalization

     42   

4.24

 

Financial Statements; No Liabilities

     43   

4.25

 

Indebtedness

     43   

4.26

 

Employee Benefit Matters

     43   

4.27

 

Employment and Labor Matters

     44   

4.28

 

Intellectual Property

     44   

4.29

 

Related Party Transactions

     45   

4.30

 

Change of Control

     45   

4.31

 

Limitations

     45   
ARTICLE 5   
REPRESENTATIONS AND WARRANTIES OF ACQUIROR PARTIES   

5.1

 

Existence and Qualification

     46   

5.2

 

Power

     46   

5.3

 

Authorization and Enforceability

     46   

5.4

 

No Conflicts

     47   

5.5

 

Consents, Approvals or Waivers

     47   

5.6

 

Litigation

     47   

5.7

 

Financing

     48   

5.8

 

Investment Intent

     48   

5.9

 

Investment Company

     48   

5.10

 

Independent Investigation

     48   

5.11

 

Liability for Brokers’ Fees

     48   

5.12

 

Bankruptcy

     48   

5.13

 

Valid Issuance

     49   

5.14

 

Capitalization

     49   

5.15

 

SEC Documents, Financial Statements, No Liabilities

     50   

5.16

 

Internal Controls; Listing Exchange

     51   

5.17

 

Compliance with Law

     51   

5.18

 

Absence of Certain Changes

     51   

5.19

 

Form S-3

     52   

5.20

 

No Stockholder Approval

     52   

5.21

 

Taxes

     52   

5.22

 

Limitations

     52   

 

-ii-


TABLE OF CONTENTS

(continued)

 

         Page  
ARTICLE 6   
COVENANTS OF THE PARTIES   

6.1

 

Access

     52   

6.2

 

Press Releases

     53   

6.3

 

Operation of Business

     53   

6.4

 

Indemnity Regarding Access

     57   

6.5

 

Hedges

     57   

6.6

 

Enforcement of Third Party Provisions

     57   

6.7

 

Governmental Reviews

     57   

6.8

 

No Shop

     58   

6.9

 

Audits and Filings

     59   

6.10

 

Conduct of Acquiror Group

     60   

6.11

 

Listing of Unit Purchase Price

     61   

6.12

 

Reserved

     61   

6.13

 

New Properties

     61   

6.14

 

Employees

     61   

6.15

 

Termination of Affiliate Agreements

     65   

6.16

 

Further Assurances

     65   

6.17

 

Credit Agreement Consent

     65   

6.18

 

Amendment of Acquiror LLC Agreement

     66   

6.19

 

Amendment of Existing Registration Rights Agreement

     66   

6.20

 

Execution of Closing Deliverables

     66   
ARTICLE 7   
CONDITIONS TO CLOSING   

7.1

 

Conditions of Contributor Parties to Closing

     66   

7.2

 

Conditions of Acquiror Parties to Closing

     67   
ARTICLE 8   
CLOSING   

8.1

 

Time and Place of Closing

     68   

8.2

 

Obligations of the Contributor Parties at Closing

     68   

8.3

 

Obligations of Acquiror Parties at Closing

     70   

8.4

 

Adjusted Purchase Price and Post-Closing Purchase Price Adjustments

     71   

8.5

 

Indemnity Holdback

     73   

8.6

 

Removal of Name

     76   
ARTICLE 9   
TAX MATTERS   

9.1

 

Straddle Period Tax Proration

     76   

9.2

 

Tax Returns

     77   

9.3

 

Transfer Taxes

     77   

9.4

 

Tax Cooperation

     77   

 

-iii-


TABLE OF CONTENTS

(continued)

 

         Page  

9.5

 

754 Elections

     77   

9.6

 

1031 Like-Kind Exchange Cooperation

     77   

9.7

 

Purchase Price Allocation

     78   

9.8

 

Tax Treatment

     79   
ARTICLE 10   
TERMINATION   

10.1

 

Termination

     79   

10.2

 

Effect of Termination

     80   

10.3

 

Distribution of Deposit Upon Termination; Damages for Failure to Close

     80   
ARTICLE 11   
INDEMNIFICATION; LIMITATIONS   

11.1

 

Indemnification

     81   

11.2

 

Indemnification Actions

     83   

11.3

 

Limitation on Actions

     85   
ARTICLE 12   
MISCELLANEOUS   

12.1

 

Counterparts

     87   

12.2

 

Notices

     87   

12.3

 

Expenses

     89   

12.4

 

Governing Law

     89   

12.5

 

Dispute Resolution

     89   

12.6

 

Captions

     90   

12.7

 

Waivers

     90   

12.8

 

Assignment

     90   

12.9

 

Entire Agreement

     90   

12.10

 

Amendment

     91   

12.11

 

No Third-Person Beneficiaries

     91   

12.12

 

Severability

     91   

12.13

 

Time of the Essence

     91   

12.14

 

References

     91   

12.15

 

Construction

     91   

12.16

 

Limitation on Damages

     92   

12.17

 

Contributor Representative

     92   

12.18

 

Recourse Only Against Parties

     94   

 

-iv-


TABLE OF CONTENTS

(continued)

 

 

EXHIBITS:

Exhibit A-1

   Category 1 Leases

Exhibit A-2

   Category 2 Leases

Exhibit A-3

   Category 3 Leases

Exhibit A-4

   Category 4 Leases

Exhibit B

   Wells

Exhibit C

   Form of Assignment Agreement

Exhibit D

   Form of Registration Rights and Lock-Up Agreement

Exhibit E

   Working Capital Calculation Methodology

Exhibit F

   Excluded Assets

Exhibit G

   Terms of A&R LLC Agreement

Exhibit H

   Terms of A&R Registration Rights Agreement

Exhibit I

   Form of Transition Services Agreement
SCHEDULES:

Schedule 4.1

   Company Group Interests

Schedule 4.2

   Litigation

Schedule 4.3

   Taxes and Assessments

Schedule 4.4

   Compliance with Laws

Schedule 4.5

   Material Contracts

Schedule 4.6

   Production Payments and Imbalances

Schedule 4.7

   Consents, Preferential Rights, Tag-Along Rights and Drag-Along Rights

Schedule 4.9

   Wells and Equipment

Schedule 4.10

   Non-Consent Operations

Schedule 4.11

   Outstanding Capital Commitments

Schedule 4.12

   Environmental Matters

Schedule 4.13

   Hedging Transactions

Schedule 4.16

   Certain Leases

Schedule 4.17

   Bonds, Letters of Credit and Guarantees

Schedule 4.23

   Capitalization

Schedule 4.24

   Financial Statements

Schedule 4.27

   Employment Matters

Schedule 4.28(a)

   Registered IP

Schedule 4.29

   Related Party Transactions

Schedule 6.3

   Conduct of Business

Schedule 6.10

   Conduct of Acquiror Group

Schedule 6.13

   New Properties

Schedule 6.15

   Affiliate Agreements

 

-v-


TABLE OF CONTENTS

(continued)

 

 

A&R LLC Agreement

     66   

A&R Registration Rights Agreement

     66   

Accounting Arbitrator

     72   

Acquired Entities

     1   

Acquiror

     1   

Acquiror Employer

     61   

Acquiror Family

     82   

Acquiror Group

     2   

Acquiror Group Member

     2   

Acquiror Material Adverse Effect

     2   

Acquiror Parent

     1   

Acquiror Parties

     1   

Acquiror Party Fundamental Representations

     2   

Acquiror Party Securities

     41   

Acquiror Plans

     62   

Acquiror Units

     2   

Acquiror’s Auditor

     59   

Adjusted Purchase Price

     13   

Affiliate

     2   

Affiliate Contract

     45   

Agreement

     1   

Allocated Value

     20   

Allocation Objection Notice

     78   

ANRP I

     94   

ANRP II

     94   

Asset Taxes

     3   

Assets

     3   

Assignment Agreement

     3   

Available Employees

     3   

Business Day

     3   

Cash Closing Payment

     71   

Cash Equivalents

     3   

Cash Purchase Price

     12   

Cash Reserve

     92   

Claim

     83   

Claim Notice

     83   

Class A Common Stock

     3   

Class B Common Stock

     3   

Closing

     68   

Closing Date

     68   

Code

     3   

Commission

     50   

Common Stock

     3   

Company Group

     3   

Company Group Interests

     1   

Company Group Material Adverse Effect

     3   

Company Group Member

     4   

Contracting Parties

     94   

Contracts

     4   

Contribution

     1   

Contributor

     1   

Contributor Benefit Plan

     4   

Contributor Family

     81   

Contributor Financial Statements

     43   

Contributor Group

     4   

Contributor Group Member

     4   

Contributor Parent

     1   

Contributor Parties

     1   

Contributor Party Fundamental Representations

     4   

Contributor RBL

     4   

Contributor Rep Expense Fund

     92   

Contributor Representative

     1   

Contributor Taxes

     5   

Contributor’s Designees

     71   

Control

     2   

Covenant Agreement

     94   

Credit Agreement

     47   

Credit Agreement Consent

     65   

Cure Date

     24   

Damages

     87   

DE Operating

     1   

DEEP

     1   

DEEP LLC Agreement

     93   

Defect Claim Date

     22   

Defect Escrow Account

     26   

Defect Escrow Agreement

     26   

Defect Escrow Amount

     26   

Defect Escrow Cash Amount

     26   

Defect Escrow Unit Amount

     26   

Defensible Title

     15   

Delaware LLC Act

     5   

Deposit

     13   

Deposit Damages Payment

     80   

Deposit Escrow Account

     13   
 

 

-vi-


TABLE OF CONTENTS

(continued)

 

 

Deposit Escrow Agreement

     13   

Disputed Claims

     75   

Disputed Environmental Matters

     31   

Disputed Matter

     25   

Disputed Title Matters

     31   

Effective Date

     5   

Employee Benefit Plan

     5   

Encumbrances

     5   

End Date

     79   

Entity Employees

     5   

Environmental Arbitrator

     31   

Environmental Consultant

     21   

Environmental Defect

     22   

Environmental Defect Amount

     25   

Environmental Defect Property

     24   

Environmental Information

     22   

Environmental Laws

     5   

Environmental Liabilities

     6   

Environmental Permits

     39   

Environmental Review

     21   

Equipment

     38   

ERISA

     6   

Escrow Agent

     13   

Escrowed Defect Units

     26   

Exchange

     77   

Exchange Act

     6   

Excluded Assets

     12   

Excluded Property

     6   

Execution Date

     1   

Existing Registration Rights Agreement

     66   

Filings

     59   

Final Allocation

     78   

Final Release Disputed Claims

     75   

Financial Statements

     50   

GAAP

     6   

Governmental Authority

     6   

Hazardous Materials

     6   

Hedging Portfolio

     40   

Hedging Portfolio Value Amount

     6   

Hedging Transaction

     6   

Holdback Period

     74   

HSR Act

     58   

Hydrocarbons

     7   

Income Tax

     7   

Indebtedness

     7   

Indemnified Person

     83   

Indemnifying Person

     83   

Indemnity Holdback Account

     7   

Indemnity Holdback Amount

     7   

Indemnity Holdback Cash

     73   

Indemnity Holdback Escrow Agreement

     74   

Indemnity Holdback Units

     73   

Individual Indemnity Threshold

     86   

Initial Release Disputed Claims

     75   

Intellectual Property Rights

     7   

Interest

     7   

Interim Period

     8   

Involuntary Termination

     63   

Laws

     8   

Leases

     8   

Liquidated Damages Amount

     80   

Liquidated Damages Payment

     80   

Liquidations

     1   

LLC Agreement

     8   

Lone Star

     1   

Material Breach

     80   

Material Contract

     8   

Member Fund

     92   

Member LLC

     1   

Members

     92   

Net Acres

     9   

Net Revenue Interest

     9   

Non-Competition Agreements

     9   

Nonparty Affiliates

     95   

NORM

     46   

Novus Purchase Agreement

     10   

NYSE

     51   

Organizational Documents

     10   

Parties

     1   

Party

     1   

Per Share Value

     10   

Permitted Encumbrances

     17   

Person

     10   

Phase II Environmental Assessment

     10   

Phase II Request

     21   

Pre-Effective Date Period

     10   

Preferential Purchase Right

     32   

Preliminary Settlement Statement

     71   

Pro Rata Share

     10   

Property

     10   
 

 

-vii-


TABLE OF CONTENTS

(continued)

 

 

Property Costs

     10   

Proposed Tax Allocation

     78   

Reclassification Event

     13   

Registration Rights and Lock-Up Agreement

     11   

Release

     11   

Remediation

     11   

Represented Persons

     92   

SEC Documents

     50   

Securities Act

     59   

Securities Laws

     59   

Site Assessment

     21   

Special Warranty of Title

     41   

Stock Closing Payment

     71   

Straddle Period

     11   

Subsidiary

     11   

Target Closing Date

     68   

Tax

     11   

Tax Partnership

     36   

Tax Return

     11   

Taxes

     11   

Third Party Acquisition

     59   

Title Arbitrator

     31   

Title Benefit

     17   

Title Benefit Amount

     25   

Title Benefit Property

     23   

Title Defect

     16   

Title Defect Amount

     25   

Title Defect Property

     22   

Title Defects

     16   

Transaction Agreements

     12   

Transactions

     12   

Transfer Taxes

     77   

Transferred Employees

     62   

Transition Services Termination Date

     12   

Unadjusted Purchase Price

     12   

Unit Purchase Price

     12   

Unit Recipient

     71   

Veritas

     1   

Well

     15   

Wells

     15   

Working Capital

     12   

Working Interest

     12   
 

 

-viii-


CONTRIBUTION AGREEMENT

This Contribution Agreement (this “ Agreement ”), is dated as of February 7, 2017 (the “ Execution Date ”), by and among Double Eagle Energy Permian Operating LLC, a Delaware limited liability company (“ Contributor ”), Double Eagle Energy Permian LLC, a Delaware limited liability company (“ DEEP ”), Double Eagle Energy Permian Member LLC, a Delaware limited liability company (“ Member LLC ” and, together with DEEP, the “ Contributor Parent ” and, together with DEEP and Contributor, the “ Contributor Parties ”), Parsley Energy, LLC, a Delaware limited liability company (“ Acquiror ”), Parsley Energy, Inc., a Delaware corporation (“ Acquiror Parent ” and, together with Acquiror, the “ Acquiror Parties ”), and, solely for the purposes of Section  12.17 , Double Eagle Energy HoldCo LLC, a Delaware limited liability company (the “ Contributor Representative ”). Each of the Contributor Parties, the Acquiror Parties and, after giving effect to the penultimate sentence of Section 12.17(a) , the Contributor Representative are referred to herein individually as a “ Party ” and collectively as the “ Parties ”).

RECITALS:

WHEREAS, DEEP owns 100% of the issued and outstanding Interests of Member LLC, and Member LLC and DEEP own .01% and 99.99%, respectively, of the issued and outstanding Interests of Contributor;

WHEREAS, Contributor owns 100% of the issued and outstanding Interests (the “ Company Group Interests ”) of each of Double Eagle Lone Star LLC, a Delaware limited liability company (“ Lone Star ”), DE Operating LLC, a Delaware limited liability company (“ DE Operating ”), and Veritas Energy Partners, LLC, a Delaware limited liability company (“ Veritas ” and, together with Lone Star and DE Operating, the “ Acquired Entities ”);

WHEREAS, Contributor desires to contribute to Acquiror and Acquiror desires to acquire from Contributor, all of the Company Group Interests, subject to the terms and conditions set forth in this Agreement (the “ Contribution ”);

WHEREAS, on the date hereof, certain members of the Company Group management team have executed and delivered to Acquiror the Covenant Agreement; and

WHEREAS, immediately following the Contribution, Contributor, Member LLC and DEEP will each liquidate (collectively, the “ Liquidations” ).

NOW, THEREFORE, in consideration of the premises and of the mutual promises, representations, warranties, covenants, conditions, and agreements contained herein, and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the Parties agree as follows:

ARTICLE 1

CONTRIBUTION

1.1 Contribution . On the terms and conditions contained in this Agreement, Contributor agrees to, and Contributor Parent agrees to cause Contributor to, contribute to Acquiror, and Acquiror agrees to acquire, accept, and pay for, the Company Group Interests in accordance with the terms of this Agreement.


1.2 Certain Definitions . As used herein:

(a) “ Acquiror Group ” means the Acquiror Parties and their respective Subsidiaries.

(b) “ Acquiror Group Member ” means any member of the Acquiror Group.

(c) “ Acquiror Material Adverse Effect ” means any event, condition, change, development, circumstance or set of facts that, individually or in the aggregate with any other such events, conditions, changes, developments, circumstances or sets of facts, (a) has a material adverse effect on the business, financial condition or results of operations of the Acquiror Group, taken as a whole, or (b) prevents or materially delays the performance of the Acquiror Parties’ obligations and covenants hereunder or the consummation by the Acquiror Parties of the Transactions contemplated hereby; provided , however , that the term “Acquiror Material Adverse Effect” shall not include effects (except, in the case of clauses (i)  through (vi) and (viii)  below, to the extent such effects have a disproportionate materially adverse impact on the business of the Acquiror Group relative to the businesses of other Persons operating in the same industry and geographic area in which the Acquiror Group operates) resulting from (i) general changes in oil and gas prices; (ii) general changes in economic or political conditions or markets; (iii) changes in condition or developments (including changes in applicable Law) generally applicable to the oil and gas industry; (iv) acts of God, including storms and natural disasters; (v) acts or failures to act of Governmental Authorities (where not caused by the willful or negligent acts of an Acquiror Group Member); (vi) the outbreak or escalation of hostilities involving the United States, the declaration by the United States of a national emergency or war, civil unrest or similar disorder or terrorist acts; (vii) any occurrence, condition, change, event or effect resulting from or relating to the announcement or pendency of the Transactions; (viii) any change in GAAP, or in the interpretation thereof; and (ix) any occurrence, condition, change, event or effect resulting from compliance by Acquiror Parties with the terms of this Agreement and each other Transaction Agreement, or actions expressly permitted by this Agreement or expressly at or with the written consent of Contributor.

(d) “ Acquiror Party Fundamental Representations ” means the representations and warranties of Acquiror Parties set forth in Sections 5.1 , 5.2 , 5.3 and 5.4(a) .

(e) “ Acquiror Units ” means Units (as defined in the LLC Agreement) of Acquiror having such rights, privileges and preferences of the “Units” as set forth in the LLC Agreement.

(f) “ Affiliate ” means, with respect to any Person, a Person that directly or indirectly controls, is controlled by, or is under common control with, such Person. “ Control ” and derivatives of such term, as used in this definition, means having the ability, whether or not exercised, to direct the management or policies of a Person through ownership of voting shares or other securities, pursuant to a written agreement, or otherwise.

 

-2-


(g) “ Assets ” means all of the assets and properties of the Company Group other than the Excluded Assets.

(h) “ Asset Taxes ” means ad valorem, property, excise, severance, production, sales, use and similar Taxes based upon operation or ownership of the Assets or the production of Hydrocarbons therefrom, but excluding, for the avoidance of doubt, Income Taxes and Transfer Taxes.

(i) “ Assignment Agreement ” means the Assignment Agreement in the form attached hereto as Exhibit  C .

(j) “ Available Employees ” means the employees of Contributor or its Affiliate who are listed on the list provided by Contributor to Acquiror pursuant to Section  6.14(a) .

(k) “ Business Day ” means any day other than a Saturday, a Sunday, or a day on which banks are closed for business in New York, New York or Houston, Texas, United States of America.

(l) “ Cash Equivalents ” means collectively, United States Department of the Treasury bills and bonds, commercial paper, marketable securities, money market funds, United States savings bonds and other similar highly-liquid assets.

(m) “ Class  A Common Stock ” means the Class A common stock of Acquiror Parent, par value $0.01 per share.

(n) “ Class  B Common Stock ” means the Class B common stock of Acquiror Parent, par value $0.01 per share.

(o) “ Code ” means the United States Internal Revenue Code of 1986, as amended.

(p) “ Common Stock ” means the Class A Common Stock and the Class B Common Stock.

(q) “ Company Group ” means Lone Star, DE Operating, Veritas and each of their respective Subsidiaries.

(r) “ Company Group Material Adverse Effect ” means any event, condition, change, development, circumstance or set of facts that, individually or in the aggregate with any other such events, conditions, changes, developments, circumstances or sets of facts, (a) has a material adverse effect on the Assets or the ownership, use, operation or value thereof, taken as a whole, or the business, financial condition or results of operations of the Company Group, taken as a whole, or (b) prevents or materially delays the performance of the Contributor Parties’ obligations and covenants hereunder or the consummation by the Contributor Parties of the Transactions contemplated hereby; provided, however, that the term “Company Group Material Adverse Effect” shall not include effects (except, in the case of clauses (i) through (vi) and (viii) below, to the extent such effects have a disproportionate materially adverse impact on the

 

-3-


business of the Company Group (taken as a whole) relative to the businesses of other Persons operating in the same industry and geographic area in which any Company Group Member operates) resulting from (i) general changes in oil and gas prices; (ii) general changes in economic or political conditions or markets; (iii) changes in condition or developments (including changes in applicable Law) generally applicable to the oil and gas industry; (iv) acts of God, including storms and natural disasters; (v) acts or failures to act of Governmental Authorities (where not caused by the willful or negligent acts of Contributor); (vi) the outbreak or escalation of hostilities involving the United States, the declaration by the United States of a national emergency or war, civil unrest or similar disorder or terrorist acts; (vii) any occurrence, condition, change, event or effect resulting from or relating to the announcement or pendency of the Transactions; (viii) any change in GAAP, or in the interpretation thereof; (ix) any occurrence, condition, change, event or effect resulting from compliance by Contributor or the Company Group with the terms of this Agreement and each other Transaction Agreement, or actions expressly permitted by this Agreement or expressly at or with the written consent of the Acquiror Parties; and (x) any failure of Contributor or any Company Group Member to take, or any untimely delay with respect to, any action referred to in Section 6.3 that requires the consent of the Acquiror Parties due to the Acquiror Parties’ unreasonable withholding of its consent or unreasonable delaying of its consent.

(s) “ Company Group Member ” means any member of the Company Group.

(t) “ Contracts ” means all currently existing contracts, agreements, and instruments to which any Company Group Member is a party or by which any Company Group Member is bound or to which any of the Assets or the Company Group Interests is subject, provided, however, that the term “Contracts” shall not include (A) any contracts, agreements, and instruments included within the definition of “Excluded Assets” and (B) the Leases.

(u) “ Contributor Benefit Plan ” means an Employee Benefit Plan (i) sponsored, maintained or contributed to by Contributor or an Affiliate of Contributor other than a Company Group Member, and (ii) under which any Available Employee is eligible to participate or otherwise providing compensation or benefits to any Available Employee.

(v) “ Contributor Party Fundamental Representations ” means the representations and warranties of the Contributor Parties set forth in Section  4.1(a) , (b) , (c) , (d)(i) and (f) , Section  4.8 , Section  4.22 and Section  4.23 .

(w) “ Contributor Group ” means the Contributor Parties and their respective Subsidiaries other than the Company Group Members.

(x) “ Contributor Group Member ” means any member of the Contributor Group.

(y) “ Contributor RBL ” means that certain Credit Agreement, dated as of September 30, 2016, by and among Contributor and JPMorgan Chase Bank, N.A., as administrative agent, collateral agent, swing line lender and issuing bank, and the other lenders party thereto, as amended from time to time.

 

-4-


(z) “ Contributor Taxes ” means (x) any and all Taxes imposed on the Company Group, or for which it may otherwise be liable, for (A) any Pre-Effective Date Period or (B) any portion of any Straddle Period ending before the Effective Date (determined in accordance with Section  9.1 ); provided , that Contributor Taxes shall not include the specifically included items of Tax liability of the Company Group that have decreased the amount of Working Capital; (y) any and all Taxes of the Contributor, DEEP and Member LLC, or for which each of DEEP or Member LLC may otherwise be liable; and (z) any and all Taxes relating to, or arising from the Liquidations; provided , in each case, that Contributor Taxes shall not include Transfer Taxes.

(aa) “ Delaware LLC Act ” means the Delaware Limited Liability Company Act, as amended from time to time.

(bb) “ Effective Date ” means 12:01 a.m. in Houston, Texas on January 1, 2017.

(cc) “ Employee Benefit Plan ” means any “employee benefit plan” (within the meaning of Section 3(3) of ERISA, regardless of whether such plan is subject to ERISA), and any other personnel policy (oral or written), equity option, restricted equity, equity purchase plan, other equity or equity-based compensation plan or arrangement, phantom equity or appreciation rights plan or arrangement, collective bargaining agreement, bonus plan or arrangement, incentive award plan or arrangement, vacation or holiday pay policy, retention or severance pay plan, policy or agreement, deferred compensation agreement or arrangement, change in control, hospitalization or other welfare, medical, dental, vision, accident, disability, life or other insurance, executive compensation or supplemental income arrangement, consulting agreement, employment, severance or retention agreement, and any other plan, agreement, arrangement, program, practice, or understanding providing any compensation or benefits.

(dd) “ Encumbrances” means liens, pledges, charges, encumbrances, claims, mortgages, deeds of trust, security interests, restrictions, rights of first refusal, defects in title, or other burdens, options or encumbrances of any kind.

(ee) “ Entity Employees ” means those employees of Contributor or its Affiliate whose employment principally involves providing services with respect to an Acquired Entity.

(ff) “ Environmental Laws ” means, as the same have been amended to the date hereof, the Comprehensive Environmental Response, Compensation and Liability Act, 42 U.S.C. § 9601 et seq . (“ CERCLA ”); the Resource Conservation and Recovery Act, 42 U.S.C. § 6901 et seq .; the Federal Water Pollution Control Act, 33 U.S.C. § 1251 et seq .; the Clean Air Act, 42 U.S.C. § 7401 et seq .; the Hazardous Materials Transportation Act, 49 U.S.C. § 5101 et seq .; the Toxic Substances Control Act, 15 U.S.C. §§ 2601 through 2629; the Oil Pollution Act, 33 U.S.C. § 2701 et seq .; the Emergency Planning and Community Right-to-Know Act, 42 U.S.C. § 11001 et seq .; and the Safe Drinking Water Act, 42 U.S.C. §§ 300f through 300j; the Endangered Species Act, 16 U.S.C. § 1531 et seq., in each case as amended to the date hereof, and all similar Laws as of the date hereof of any Governmental Authority having jurisdiction over the property in question addressing pollution or protection of the environment, natural resources, or biological or cultural resources and all regulations implementing the foregoing, excluding, however, all Laws relating to spacing, density, setbacks, specifications or grades for equipment or materials, well integrity or construction, and the protection of correlative rights in Hydrocarbons.

 

-5-


(gg) “ Environmental Liabilities ” means any and all environmental, corrective action and response costs (including costs of Remediation), damages, natural resource damages, settlements, consulting fees, expenses, penalties, fines, orphan share, prejudgment and post-judgment interest, court costs, attorneys’ fees and other liabilities incurred or imposed (a) pursuant to any order, notice of responsibility, directive (including requirements embodied in Environmental Laws), injunction, judgment or similar act (including settlements) by any Governmental Authority or court of competent jurisdiction to the extent arising out of any violation of, or remedial obligation under, any Environmental Laws or (b) pursuant to any claim or cause of action by a Governmental Authority or other Person for personal injury, property damage, damage to natural resources, Remediation or response costs to the extent arising out of any violation of, or any Remediation obligation under, any Environmental Laws.

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

(ii) “ Exchange Act ” means the Securities Exchange Act of 1934, as amended, and the rules and regulations thereunder.

(jj) “ Excluded Property ” has the meaning set forth in Schedule 6.13 .

(kk) “ GAAP ” means United States generally accepted accounting principles, consistently applied.

(ll) “ Governmental Authority ” means any national government and/or government of any political subdivision, and departments, courts, commissions, boards, bureaus, ministries, agencies, or other instrumentalities of any of them.

(mm) “ Hazardous Materials ” means any pollutants, contaminants, toxic or hazardous substances, materials, wastes, constituents, compounds or chemicals that are regulated by, or may form the basis of liability under any Environmental Laws, including (a) petroleum hydrocarbons, petroleum products, petroleum substances, natural gas, crude oil, or any components, fractions, or derivatives thereof, and (b) asbestos-containing materials and polychlorinated biphenyls.

(nn) “ Hedging Transaction ” means transaction that is (i) a swap, basis swap, option, collar, or similar transaction entered into “over-the-counter”, (ii) involving, or settled by reference to, one or more commodities, and (iii) intended to hedge the risks associated with the production of Hydrocarbons.

(oo) “ Hedging Portfolio Value Amount ” means, on any date of determination in respect of the Hedging Transactions included in the Hedging Portfolio, after taking into account the effect of any legally enforceable netting agreement relating to such Hedging Transactions, the aggregate amount of losses or costs that would be incurred under then prevailing conditions by the Contributor

 

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Group Member party thereto (expressed as a positive number) or gains that would be realized under then prevailing conditions by the Contributor Group Member party thereto (expressed as a negative number) in replacing, or in providing for such Contributor Group Member, the economic equivalent of the material terms of such Hedging Transactions (including payments that would be required after the date of determination) and the option rights in respect of such Hedging Transactions, as agreed by the Contributor and Acquiror.

(pp) “ Hydrocarbons ” means crude oil, gas, casinghead gas, condensate, natural gas liquids, and other gaseous or liquid hydrocarbons (including, without limitation, ethane, propane, iso-butane, nor-butane, gasoline, and scrubber liquids) of any type and chemical composition.

(qq) “ Income Tax ” shall mean any income, capital gains, franchise and similar Tax.

(rr) “ Indebtedness” of any Person means, without duplication: (i) indebtedness of such Person for borrowed money; (ii) obligations of such Person to pay the deferred purchase or acquisition price for any property of such Person; (iii) reimbursement obligations of such Person in respect of drawn letters of credit or similar instruments issued or accepted by banks and other financial institutions for the account of such Person; (iv) obligations of such Person under a lease to the extent such obligations are required to be classified and accounted for as a capital lease on a balance sheet of such Person under GAAP; (v) indebtedness, commitment fees or other obligations of such Person with respect to (A) that certain Note Purchase Agreement, dated as of November 7, 2016, by and among Contributor, the Initial Investors (as defined therein) party thereto and Magnetar Financial LLC and/or (B) that certain Indenture, dated November 7, 2016, among Contributor and Wilmington Trust, National Association as trustee and (vi) indebtedness of others as described in clauses (i)  through (v) above guaranteed by such Person; but Indebtedness does not include accounts payable to trade creditors or accrued expenses, in each case arising in the ordinary course of business consistent with past practice and that are not yet due and payable, or are being disputed in good faith, and the endorsement of negotiable instruments for collection in the ordinary course of business.

(ss) “ Indemnity Holdback Amount ” means the sum of (i) the aggregate number of Indemnity Holdback Units multiplied by the Per Share Value and (ii) the Indemnity Holdback Cash.

(tt) “ Indemnity Holdback Escrow Account ” means the escrow account established by the Indemnity Holdback Escrow Agreement.

(uu) “ Intellectual Property Rights ” means rights in any of the following to the extent subject to protection under applicable Law: (a) trademarks, service marks, logos and trade names; (b) patents; (c) copyrights; (d) internet domain names; (e) trade secrets and other proprietary and confidential information; and (f) any registrations or applications for registration for any of the foregoing.

(vv) “ Interest ” means, with respect to any Person: (i) capital stock, membership interests, partnership interests, other equity interests, rights to profits or revenue and any other similar interest of such Person; (ii) any security or other interest convertible into or exchangeable or exercisable for any of the foregoing; and (iii) any right (contingent or otherwise) to subscribe for, purchase or otherwise acquire any of the foregoing.

 

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(ww) “ Interim Period ” means the period beginning upon the Effective Date and ending upon the Closing Date.

(xx) “ Laws ” means all laws, statutes, rules, regulations, ordinances, orders, decrees, requirements, judgments, and codes of Governmental Authorities.

(yy) “ Leases ” means oil and gas leases, oil, gas, and mineral leases and subleases, and other similar agreements described on Exhibit  A under which any Company Group Member leases or otherwise acquires or obtains rights or interests in and to Hydrocarbons.

(zz) “ LLC Agreement ” means that certain First Amended and Restated Limited Liability Company Agreement of Acquiror, dated as of May 29, 2014.

(aaa) “ Material Contract ” means any Contract which is one or more of the following types:

(i) Organizational Documents of any Company Group Member or any other Person in which any Company Group Member owns an Interest;

(ii) contracts with any Contributor Group Member or any of their Affiliates other than contracts solely between or among the Acquired Entities and their wholly-owned Subsidiaries;

(iii) contracts for the sale, purchase, exchange, or other disposition of Hydrocarbons of the Company Group that (A) are not cancelable without penalty to any Company Group Member, on at least sixty (60) days prior written notice, or (B) obligate any Company Group Member by virtue of any material take-or-pay payment, advance payment, production payment, or other similar material payment (other than royalties or other burdens on Hydrocarbon production established in any Leases or any such obligations reflected on Exhibit  A ), to deliver Hydrocarbons, or proceeds from the sale thereof, attributable to any Company Group Member’s interest in the Properties at some future time without receiving payment therefor at or after the time of delivery of such Hydrocarbons;

(iv) contracts to sell, lease, farmout, trade, exchange, or otherwise dispose of any material amount of the Assets of the Company Group, taken as a whole, but excluding conventional rights of reassignment upon intent to abandon or release a Well or Lease;

(v) joint operating agreements, unit operating agreements, unit agreements, exploration agreements, development agreements (including all such contracts containing express unfulfilled obligations for any Company Group Member to drill additional wells), area of mutual interest agreements (or other contracts containing area of mutual interest provisions), or other similar agreements requiring any Company Group Member to make expenditures that would reasonably be expected to be in excess of $100,000 in the aggregate during the twelve (12)-month period following the Execution Date, other than customary joint operating agreements;

 

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(vi) any contracts under which any Company Group Member has the right to be “carried” by another Person (i.e. have another Person pay its share of costs and expenses) or the obligation to “carry” another Person (i.e. pay the costs and expenses of another Person) with respect to, or in connection with, the ownership, operation or development of the Properties;

(vii) non-competition agreements or any agreements that restrict, limit, or prohibit any Company Group Member from engaging in any line of business or the manner in which, or the locations at which, any Company Group Member conducts business, including area of mutual interest agreements, during any period of time after the Closing (“ Non-Competition Agreements ”);

(viii) contracts for the gathering, treatment, processing, storage, disposal or transportation of Hydrocarbons or water, surface use agreements, and any contracts that contain dedications or volume commitments which are binding on any Company Group Member;

(ix) indentures, mortgages or deeds of trust, loans, credit or note purchase agreements, sale-lease back agreements, guaranties, bonds, letters of credit, or similar financial agreements or other agreements or instruments governing Indebtedness;

(x) contracts for the construction and installation or rental of equipment, fixtures, or facilities with guaranteed production throughput requirements or demand charges or involving aggregate payments per contract in excess of $100,000 in any calendar year, which, in either case, cannot be terminated by a Company Group Member without penalty on sixty (60) days or less notice; and

(xi) agreements, excluding joint operating agreements, that could reasonably be expected to result in (A) aggregate payments by the Company Group Members (net to the interest of the Company Group taken as a whole) of more than $100,000 or (B) revenues (net to the interest of Contributor) of more than $100,000 during the current or any subsequent calendar year.

(bbb) “ Net Acres ” means, as calculated separately with respect to each Lease as to the lands and depths described for such Lease in Exhibit A , (i) the number of gross acres of land covered by such Lease, multiplied by (ii) the lessor’s (or fee mineral interest owner’s) undivided interest in the lands covered by such Lease, multiplied by (iii) the applicable Company Group Member’s undivided interest in such Lease ( provided , however , if items (ii) and/or (iii) vary as to different areas of, or depths under, the lands covered by such Lease, a separate calculation shall be performed with respect to each such area or depth).

(ccc) “ Net Revenue Interest ” means, (i) with respect to any Well, the applicable Company Group Member’s interest (expressed as a percentage or a decimal) in and to the Hydrocarbons produced and saved or sold from or allocated to such Well from those formations in which such Well is currently producing, or with respect to a Well that is not currently producing, the last depth or formation at which it produced, or (ii) with respect to any Lease, the applicable Company Group Member’s interest (expressed as a percentage or a decimal) in and to

 

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the Hydrocarbons produced and saved or sold from or allocated to such Lease as to the lands and depths described for such Lease on Exhibit A , in the case of each of items (i) and (ii), after giving effect to all royalties, overriding royalties, nonparticipating royalties, net profits interests, production payments, carried interests, reversionary interests and other burdens on, measured by or payable out of Hydrocarbon production therefrom.

(ddd) “ Novus Purchase Agreement ” means that certain Membership Interest Purchase and Sale Agreement between MCM Energy Partners, LLC and Double Eagle Lone Star LLC, dated February 3, 2017.

(eee) “ Organizational Documents ” means (i) with respect to a corporation, the charter, articles or certificate of incorporation, as applicable, and bylaws thereof, (ii) with respect to a limited liability company, the certificate of formation or organization, as applicable, and the operating or limited liability company agreement thereof, (iii) with respect to a partnership, the certificate of formation and the partnership agreement thereof, and (iv) with respect to any other Person, the organizational, constituent and/or governing documents and/or instruments of such Person.

(fff) “ Per Share Value ” means $35.00.

(ggg) “ Person ” means any individual, corporation, partnership, limited liability company, trust, estate, Governmental Authority, or any other entity.

(hhh) “ Phase II Environmental Assessment ” means an intrusive investigation which collects original samples of soil, groundwater, other environmental media, air or building materials to analyze for quantitative values of contaminants of concern for purposes of identifying any Recognized Environmental Condition or any Historical Recognized Environmental Condition (as such terms are defined in ASTM Standard Practice E1903-11 for Environmental Site Assessments: Phase II Environmental Site Assessment Process).

(iii) “ Pre-Effective Date Period ” means any Tax period ending before the Effective Date.

(jjj) “ Property ” means any Lease identified on Exhibit A or any Well identified on Exhibit B , excluding any Well or Lease that becomes an Excluded Property.

(kkk) “ Property Costs ” means all operating expenses (including costs of insurance, rentals, shut-in payments) and capital expenditures (including bonuses, and other Lease acquisition costs, costs of drilling and completing wells, and costs of acquiring equipment) incurred in the ownership and operation of the Assets in the ordinary course of business, and overhead costs charged to the Assets under the applicable operating agreement, but excluding (without limitation) liabilities, losses, costs, and expenses incurred after the Execution Date to cure Title Defects or Environmental Defects and costs incurred during the Interim Period to acquire any Lease, Well, New Lease or New Well.

(lll) “ Pro Rata Share ” means, with respect to each Unit Recipient, a fraction, the numerator of which is the number of Acquiror Units to be issued to such Unit Recipient as part of the Stock Closing Payment as set forth in the Preliminary Settlement Statement and the denominator of which is the total number of Acquiror Units comprising the Stock Closing Payment.

 

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(mmm) “ Registration Rights and Lock-Up Agreement ” means the Registration Rights Agreement in the form attached hereto as Exhibit  D to be executed and delivered by Acquiror Parent and Contributor (and Contributor’s Designees receiving a portion of the Unit Purchase Price) at Closing.

(nnn) “ Release ” means any depositing, spilling, leaking, pumping, pouring, placing, emitting, discarding, abandoning, emptying, discharging, migrating, injecting, escaping, leaching, dumping, or disposing into the environment.

(ooo) “ Remediation ” including the correlative term “Remediate” means the implementation and completion of any investigative, remedial, removal, response, monitoring, construction, repair, closure, disposal, restoration or other corrective actions (including any necessary filings or interactions with Governmental Authorities) required under Environmental Laws to respond, to the extent required by applicable Environmental Laws, to any Release or threatened Release of any Hazardous Materials at, on, under or from any Asset, in the most cost-effective manner allowed under applicable Environmental Laws.

(ppp) “ Straddle Period ” means any Tax period beginning before and ending on or after the Effective Date.

(qqq) “ Subsidiary ” means, with respect to a Person, any Person, whether incorporated or unincorporated, of which (i) at least fifty percent (50%) of the securities or ownership interests having by their terms ordinary voting power to elect a majority of the board of directors or other Persons performing similar functions, (ii) a general partner interest or (iii) a managing member interest, is directly or indirectly owned or controlled by the subject Person or by one or more of its respective Subsidiaries.

(rrr) “ Tax ” or “ Taxes ” means (i) all taxes, assessments, fees, unclaimed property and escheat obligations, and other charges of any kind whatsoever imposed by any Governmental Authority, including any federal, state, local and/or foreign income tax, surtax, remittance tax, presumptive tax, net worth tax, special contribution tax, production tax, severance tax, value added tax, withholding tax, gross receipts tax, windfall profits tax, profits tax, ad valorem tax, personal property tax, real property tax, sales tax, goods and services tax, service tax, transfer tax, use tax, excise tax, premium tax, stamp tax, motor vehicle tax, entertainment tax, insurance tax, capital stock tax, franchise tax, occupation tax, payroll tax, employment tax, unemployment tax, disability tax, alternative or add-on minimum tax and estimated tax, (ii) any interest, fine, penalty or additions to tax imposed by a Governmental Authority in connection with any item described in clause (i) , and (iii) any liability in respect of any item described in clauses (i)  or (ii) above, that arises by reason of a contract, assumption, transferee or successor liability, operation of Law (including by reason of participation in a consolidated, combined or unitary Tax Return) or otherwise.

 

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(sss) “ Tax Return ” shall mean any report, return, information statement, schedule, attachment, payee statement or other information required to be provided or provided to any Governmental Authority with respect to Taxes or any amendment thereof, including any return of an affiliated, combined or unitary group, and any and all work papers relating to any Tax Return.

(ttt) “ Transaction Agreements ” means this Agreement and each other agreement to be executed and delivered pursuant hereto at the Closing.

(uuu) “ Transactions ” means the transactions contemplated by this Agreement and the Transaction Agreements.

(vvv) “ Transition Services Termination Date ” means the date that the Term (as defined in the Transition Services Agreement) of the Transition Services Agreement ends.

(www) “ Working Capital ” means, with respect to any Person, as of the Effective Date, the positive or negative amount obtained, without duplication, by subtracting (x) the sum of all current liabilities of such Person (but excluding, any deferred Tax liabilities) from (y) the sum of all accounts receivable, cash and Cash Equivalents and other current assets of such Person (but excluding, any deferred Tax assets); provided , however , with respect to the Company Group, Working Capital shall be calculated in accordance with the methodology and the examples as set forth on Exhibit  E .

(xxx) “ Working Interest ” means, with respect to any Well, the interest (expressed as a percentage or a decimal) that is burdened with the obligation to bear and pay costs and expenses of maintenance, development and operations for that Well from those formations in which such Well is currently producing, or with respect to a Well that is not currently producing, the last depth or formation at which it produced, in each case, without regard to the effect of any royalties, overriding royalties, nonparticipating royalties, net profits interests, production payments, carried interests, reversionary interests and other burdens on, measured by or payable out of production therefrom.

1.3 Excluded Assets . Notwithstanding anything to the contrary in this Agreement, prior to Closing, Contributor shall have the right to cause the Company Group to assign to Contributor or its designees all of the Company Group’s right, title and interest in and to the assets, properties and rights set forth on Exhibit F (such assigned interests, the “ Excluded Assets ”).

ARTICLE 2

PURCHASE PRICE

2.1 Purchase Price .

(a) The total consideration to be paid for the Company Group Interests will consist of (i) cash in the aggregate amount of One Billion Three Hundred Seventy-Eight Million Thirty-Six Thousand and Sixty-One and NO/100 Dollars ($1,378,036,061.00) (as adjusted by the last sentence of this Section 2.1(a) , the “ Cash Purchase Price ) plus (ii) Thirty-Nine Million Three Hundred Seventy-Two Thousand Four Hundred Fifty-Nine (39,372,459) Acquiror Units (as adjusted by the last sentence of this Section 2.1(a) , the “ Unit Purchase Price ” and, together with the Cash Purchase Price, the “ Unadjusted Purchase Price ”; provided, that where the context

 

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indicates that the term “Unit Purchase Price” refers to a dollar amount rather than a number of Acquiror Units, including as a component of the Unadjusted Purchase Price, such term shall refer to such number of Acquiror Units multiplied by the Per Share Value), adjusted as provided in Section  2.2 (as adjusted, the “ Adjusted Purchase Price ”). In addition, Acquiror Parent agrees to issue to Contributor a number of shares of Class B Common Stock equal to the number of Acquiror Units issued to Contributor as set forth in clause (ii) . Notwithstanding the above, the Acquiror may elect, by delivery of written notice to the Contributor within two (2) Business Days following the date hereof, to increase the Cash Purchase Price and to correspondingly reduce the Unit Purchase Price by the amount of any such increase in the Cash Purchase Price divided by the Per Share Value.

(b) Within two (2) Business Days after date of the execution and delivery of this Agreement, Acquiror has delivered or will deliver to an account (the “ Deposit Escrow Account ) with Wells Fargo Bank, National Association (the “ Escrow Agent ”), a wire transfer in the amount equal to five percent (5%) of the Unadjusted Purchase Price in same-day funds (such amount, plus any interest or earnings thereon, the “ Deposit ”) to be held, invested, and disbursed in accordance with the terms of this Agreement and an escrow agreement dated as of a date within two (2) Business Days of the date hereof among Contributor, Acquiror and Escrow Agent (the “ Deposit Escrow Agreement ”). At and in connection with the Closing, Acquiror and Contributor shall execute and deliver joint written instructions to the Escrow Agent authorizing the Escrow Agent to distribute the Deposit to Contributor as part of the Cash Purchase Price. If this Agreement is terminated, the Deposit shall be disbursed in accordance with Section  10.3 .

(c) If, at any time on or after the Execution Date and prior to the Closing Date, (i) Acquiror and/or Acquiror Parent makes (A) any Common Stock or Acquiror Unit dividend or distribution, (B) subdivision or split of any Common Stock or Acquiror Units, (C) combination or reclassification of Common Stock or Acquiror Units into a small number of shares of Common Stock or Acquiror Units or (D) issuance of any securities by reclassification of Common Stock or Acquiror Units (including any reclassification in connection with a merger, consolidation or business combination in which the Acquiror Parent or Acquiror, as applicable, is the surviving person) or (ii) any merger, consolidation, combination, or other transaction is consummated pursuant to which Common Stock or Acquiror Units are converted to cash or other securities (each of clauses (i)  and (ii) , a “ Reclassification Event ”), then the Unit Purchase Price, the number of shares of Class B Common Stock to be issued at Closing pursuant to the penultimate sentence of Section  2.1(a) and the Per Share Value shall be proportionately adjusted, including, for the avoidance of doubt, in the cases of clauses (i)(C) and (ii)  to provide for the receipt by Contributor, in lieu of any Acquiror Unit comprising the Unit Purchase Price, the same number or amount of cash and/or securities as is received in exchange for each share of Common Stock and/or Acquiror Unit in connection with any such transaction described in clauses (i)(C) and (ii)  of this Section  2.1(c) . An adjustment made pursuant to the foregoing shall become effective immediately after the record date in the case of a dividend and shall become effective immediately after the effective date in the case of a subdivision, split, combination, or reclassification.

 

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2.2 Adjustments to Purchase Price .

(a) General . The Unadjusted Purchase Price shall be adjusted at Closing in accordance with this Section  2.2 , and shall be adjusted by increasing or decreasing, as applicable, both the Cash Purchase Price and the Unit Purchase Price pro rata based on the proportions that each bears to the total Unadjusted Purchase Price. With respect to any such adjustments that occur in Acquiror Units, the increase or decrease in the Unit Purchase Price shall be equal to the number of Acquiror Units obtained by dividing (x) the portion of the aggregate adjustments made under Section  2.2(b) to be made in Acquiror Units by (y) the Per Share Value; provided , however , that in the event that the total number of Acquiror Units to be issued to Contributor pursuant to Section 2.1(a) and this Section  2.2(a) would exceed 46,346,938 Acquiror Units, the number of shares of Class B Common Stock and Acquiror Units delivered at the Closing will each be reduced by the number of such excess Acquiror Units and the Cash Purchase Price shall be increased by an amount equal to the product of the number of such excess Acquiror Units multiplied by the Per Share Value.

(b) Adjustments . At Closing, the Unadjusted Purchase Price shall be adjusted as follows (without duplication):

(i) increased by the positive amount of Working Capital of each Company Group Member as of the Effective Date;

(ii) increased by the sum of (i) the amount of all cash and Cash Equivalents contributed to any Company Group Member during the Interim Period by Contributor or any Person who, directly or indirectly, owns an equity interest in Contributor, and (ii) the amount paid by Contributor (or any Person who directly or indirectly owns any interest in Contributor) in respect of any Property Costs incurred by the Company Group during the Interim Period;

(iii) decreased by the amount of all cash and Cash Equivalents of each Company Group Member distributed by such Company Group Member during the Interim Period to Contributor or any of its Affiliates (other than distributions by any Subsidiary of an Acquired Entity to any other Company Group Member), but excluding from this Section  2.2(b)(iii) for the avoidance of doubt, any amounts paid by the applicable Company Group Member to Contributor or any of its Affiliates in the ordinary course of business and consistent with past practice for goods, services and overhead;

(iv) decreased by the sum of (i) the amount of all costs incurred by any Company Group Member during the Interim Period in connection with the acquisition of any Lease, Well, New Lease or New Well plus (ii) the amount paid by the Company Group for the purchase of 15% of the equity of Novus Land Services LLC pursuant to the Novus Purchase Agreement;

(v) decreased by the negative amount of Working Capital of each Company Group Member as of the Effective Date;

(vi) decreased by the Defect Escrow Amount;

 

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(vii) decreased as provided in Section  3.8(d) ;

(viii) decreased by the Indemnity Holdback Amount;

(ix) decreased by the amount of costs incurred by the Company Group between the Execution Date and Closing Date to cure any Title Defect or Environmental Defect;

(x) increased by the Hedging Portfolio Value Amount as of February 3, 2017 if such amount is positive, or decreased by the absolute value of the Hedging Portfolio Value Amount as of February 3, 2017 if such amount is negative; and

(xi) increased by the amount of any payments made by a Contributor Group Member in respect of a Hedging Transaction included in the Hedging Portfolio subsequent to February 3, 2017 and prior to the Closing and decreased by the amount of any payments made to a Contributor Group Member in respect of a Hedging Transaction included in the Hedging Portfolio subsequent to February 3, 2017 and prior to the Closing.

2.3 Withholding . Acquiror Parties shall be entitled to deduct and withhold from any consideration otherwise payable or deliverable to Contributor such amounts as may be required to be deducted or withheld therefrom under the Code, under any Tax law or pursuant to any other applicable Law. Acquiror Parties shall use commercially reasonable efforts to provide Contributor with advance notice of intent to withhold any amount payable to Contributor. To the extent such amounts are so deducted or withheld, such amounts shall be treated for all purposes as having been paid to the Person to whom such amounts would otherwise have been paid absent such deduction or withholding.

ARTICLE 3

CERTAIN TITLE AND ENVIRONMENTAL MATTERS

3.1 Company Group s Title . Except as provided in Section  4.19 and without limitation of Acquiror’s rights under this Article  3 or under (or with respect to) Article  4 , Article  6 , or Article  11 , the certificate to be delivered by Contributor at Closing pursuant to Section  8.2(c) , pursuant to Schedule 6.13 , and the Defect Escrow Agreement, Contributor makes no representation or warranty, express or implied, statutory or otherwise, with respect to title to any of the assets or properties of the Contributor Group, and the sole remedy for any Title Defect or any other title defect with respect to any of the assets or properties of the Contributor Group shall be set forth in Article  3 , Schedule 6.13 and the Defect Escrow Agreement.

3.2 Definition of Defensible Title .

(a) As used in this Agreement, the term “ Defensible Title ” means, with respect to the Leases and Wells, that title of the Company Group Members which as of the Defect Claim Date and as of the Closing Date, or with respect to any New Properties, as of the end of the title review period as determined in Schedule 6.13 , subject to the Permitted Encumbrances:

 

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(i) with respect to each well listed on Exhibit B (each, a “ Well ” and, collectively, “ Wells ”), entitles the applicable Company Group Member to not less than the Net Revenue Interest set forth in Exhibit  B for such Well throughout the productive life thereof, except (A) decreases in connection with those operations in which the applicable Company Group Member may elect, in compliance with the terms of this Agreement, after the date hereof to be a non-consenting co-owner, (B) decreases resulting from the establishment or amendment, after the date hereof, of (1) pools or units and (2) allocations to horizontal laterals, (C) decreases resulting from any reversion of interest to co-owners with respect to operations in which such co-owners elect after the date hereof not to consent, (D) decreases required to allow other working interest owners to make up past underproduction or pipelines to make up past underdeliveries, and (E) as expressly stated in Exhibit  B ;

(ii) with respect to each Well set forth on Exhibit B , obligates the applicable Company Group Member to bear a Working Interest for such Well that is not greater than the Working Interest set forth in Exhibit  B for such Well without increase throughout the productive life of such Well, except (A) as expressly stated in Exhibit  B, (B) increases resulting from contribution requirements with respect to defaulting or non-consenting co-owners under applicable operating agreements or applicable Law, (C) increases to the extent such increases result from co-owners electing under applicable operating agreements or forced pooling orders not to participate in an operation relating to such Well, and (D) increases that are accompanied by at least a proportionate increase in the applicable Company Group Member’s Net Revenue Interest for such Well;

(iii) with respect to each Lease on Exhibit  A , entitles the applicable Company Group Member to ownership of not less than the Net Acres set forth in Exhibit  A for such Lease, as to the lands and depths described for such Lease on Exhibit  A , and entitles the applicable Company Group Member to not less than the Net Revenue Interest set forth in Exhibit  A for such Lease, as to the lands and depths described for such Lease on Exhibit  A , in each case throughout the productive life of such Lease except for, in each case, (A) decreases in connection with those operations in which the applicable Company Group Member may elect, in compliance with the terms of this Agreement, after the date hereof to be a non-consenting co-owner, (B) decreases resulting from the establishment or amendment, after the date hereof, of (1) pools or units and (2) allocations to horizontal laterals, (C) decreases resulting from any reversion of interest to co-owners with respect to operations in which such co-owners elect after the date hereof not to consent, (D) decreases required to allow other working interest owners to make up past underproduction or pipelines to make up past underdeliveries, and (E) as expressly stated in Exhibit  A ; and

(iv) is free and clear of liens, encumbrances, obligations, or defects, other than Permitted Encumbrances.

(b) As used in this Agreement, the term “ Title Defect ” means any lien, charge, encumbrance, obligation, or defect, including a discrepancy in Net Acres, Net Revenue Interest or Working Interest, that causes the applicable Company Group Member’s title to any Lease or Well described on Exhibit  A or Exhibit  B to be less than Defensible Title; provided , however , that the following shall not be considered “ Title Defects ” for purposes of this Agreement:

 

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(i) defects based on a gap in any chain of title in the county records prior to January 1, 1990;

(ii) defects arising from any change in applicable Laws after the Execution Date;

(iii) defects arising from prior expired Hydrocarbon leases that are not surrendered or released of record absent affirmative evidence of an adverse claim by another Person that such lease is in full force and effect;

(iv) defects based solely on any Company Group Member’s change (or desired change) in the surface or bottom hole location, borehole or drainhole path, well or operational plan, or operational technique (including completion or stimulation technique);

(v) production payments that have expired by their own terms absent affirmative evidence of an adverse claim by another Person that such production payment is in full force and effect;

(vi) defects based solely on any Company Group Member’s failure to have a title opinion or title insurance policy on any Property; and

(vii) mortgages or liens that are unenforceable under applicable statutes of limitations.

(c) As used in this Agreement, the term “ Title Benefit ” means any right, circumstance, or condition that operates to (i) increase the Net Revenue Interest of the applicable Company Group Member in any Property above that shown for such Property on Exhibit  A or Exhibit  B , without causing a greater than proportionate increase in, with respect to any Property that is a Well, such Company Group Member’s Working Interest in such Property, (ii) increase the Net Acre ownership of the applicable Company Group Member in any Lease above that shown for such Lease on Exhibit  A without causing a decrease in such Company Group Member’s Net Revenue Interest below that shown for such Lease on Exhibit  A , or (iii) decrease the Working Interest of the applicable Company Group Member in any Well below that shown for such Well on Exhibit  B without causing a proportionate or greater than proportionate decrease in such Company Group Member’s Net Revenue Interest in such Well.

3.3  Definition of Permitted Encumbrances . As used in this Agreement, the term “ Permitted Encumbrances ” means any or all of the following:

(a) lessors’ royalties and any overriding royalties, reversionary interests, back-in interests, and other burdens to the extent that they do not, in the aggregate, reduce the Company Group’s Net Revenue Interest or Net Acre ownership in any Property below that shown on Exhibit  A or Exhibit  B , as applicable, for such Property or increase the Company Group’s Working Interest in any Well above that shown on Exhibit  B without a corresponding and proportionate increase in the Company Group’s Net Revenue Interest for such Well;

 

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(b) all unit agreements, pooling agreements, Leases, Contracts, operating agreements, including provisions for penalties, suspensions, or forfeitures contained therein, to the extent that they do not, in the aggregate, reduce the Company Group’s Net Revenue Interest or Net Acre ownership in any Property below that shown in on Exhibit  A or Exhibit  B , as applicable, for such Property or increase the Company Group’s Working Interest in any Well above that shown on Exhibit  B without a corresponding and proportionate increase in the Company Group’s Net Revenue Interest for such Well;

(c) Preferential Purchase Rights with respect to the Assets of the Company Group;

(d) third-Person consent requirements and similar restrictions (i) that are not applicable to the Transactions contemplated by this Agreement, (ii) if unconditional waivers or consents for such consent requirements or similar restrictions are obtained from the appropriate Persons prior to the Closing Date, or (iii) to the extent relating to Excluded Assets;

(e) liens for current period Taxes or assessments not yet delinquent, or if delinquent, being contested reasonably and by appropriate actions, and for which adequate cash reserves are maintained for the payment thereof in accordance with GAAP;

(f) materialman’s, mechanic’s, repairman’s, employee’s, contractor’s, operator’s, and other similar liens or charges arising in the ordinary course of business for amounts not yet delinquent, or if delinquent, being contested reasonably and by appropriate actions, and for which adequate cash reserves are maintained for the payment thereof in accordance with GAAP;

(g) all rights to consent, by required notices to, filings with, or other actions by Governmental Authorities that do not apply to the Transactions contemplated by this Agreement or, if they do apply, are customarily obtained subsequent to the closing of transactions that are similar to the Transactions contemplated by this Agreement if such Governmental Authority is, pursuant to applicable Law, without discretion to refuse to grant such consent if specifically enumerated conditions set forth in such applicable Law are satisfied;

(h) rights of reassignment arising upon final intention to abandon or release the Assets, or any of them, to the extent such rights are not ripe;

(i) easements, rights-of-way, covenants, servitudes, permits, surface leases and other rights to use the surface, and other rights in respect of surface operations to the extent that they do not, individually or in the aggregate, materially impair the use, ownership, or operation of any Property;

(j) zoning and planning ordinances and municipal regulations;

(k) any statutory liens created under the Laws of the State of Texas and any Encumbrances created under the operating agreements or by operation of Law in respect of obligations that are not yet due;

(l) any Encumbrances affecting the Assets that are discharged by or on behalf of Contributor or the Company Group at or prior to Closing;

 

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(m) any Encumbrances burdening a third party lessor’s or grantor’s interest in the Assets (including any Encumbrances created under deeds of trust, mortgages and similar instruments by any such lessor or grantor), which, if not subordinated to the rights of Company Group, is not currently in default or subject to foreclosure or other enforcement proceedings by the holder of such Encumbrance;

(n) depth severances or any other change in the Working Interest, the Net Revenue Interest or the Net Acre ownership of the Company Group in any Property with depth to the extent that they do not, individually or in the aggregate, reduce the Company Group’s Net Revenue Interest or Net Acre ownership in any Property below that shown in on Exhibit  A or Exhibit  B , as applicable, for such Property or increase the Company Group’s Working Interest in any Well beyond that shown on Exhibit  B without a corresponding and proportionate increase in the Company Group’s Net Revenue Interest for such Well;

(o) any Encumbrances created by Law or reserved in the Leases for royalties, bonus or rental, or created to secure compliance with the terms of the Leases, provided that, in each such case, the Company Group is then in compliance with the terms of such Leases in all material respects and the respective lessor has no cause or right to enforce or execute on such Encumbrances;

(p) the terms and conditions of, and any rights of third parties to back into any interest in the Assets to the extent such terms, conditions and rights are expressly shown as binding on the applicable Property on Exhibit  A and/or Exhibit  B ;

(q) any defect arising out of a lack of corporate or entity authorization, arising from a failure to recite marital status or arising out of omissions of successions of heirship or estate proceedings, except in each case where evidence is available that reasonably supports a third party’s claim that Defensible Title does not exist;

(r) lack of a survey of the surface of the Properties, unless a survey is required by Law;

(s) all rights reserved to or vested in any Governmental Authorities to control or regulate any of the Properties in any manner or to assess Tax with respect to the Properties, the ownership, use or operation thereof, or revenue, income or capital gains with respect thereto; and all obligations and duties under all applicable Laws of any such Governmental Authority or under any franchise, grant, license or permit issued by any Governmental Authority;

(t) failure to record Leases issued by any Governmental Authority (which, for the avoidance of doubt, includes any state agency or any successor agency thereto) in the real property, conveyance, or other records of the county in which such Leases are located, provided that the instruments evidencing the conveyance of such title to any Company Group Member from its immediate predecessor in title are recorded with the Governmental Authority that issued any such Lease;

(u) any matter that has been cured, released or waived by any Law of limitation or prescription, including adverse possession and the doctrine of laches, in each case, and which can be substantiated by the affirmative ruling of a court of competent jurisdiction;

 

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(v) rights of any (i) common owner of any interest in any fee mineral interest as tenants in common or through common ownership, (ii) owner or lessee of any oil and gas interests in formations, strata, horizons, or depths other than the depths described for the applicable Lease described on Exhibit  A or (iii) common owner of any interest in surface rights currently held by the Company Group and such common owner as tenants in common or through common ownership;

(w) any other Encumbrances, burdens or irregularities which are (i) based solely on a lack of information in the Company Group’s files or of record, (ii) based solely on references to any document if a copy of such document is not in the Company Group’s files or of record, or (iii) based solely on the inability to locate an unrecorded instrument of which Acquiror has constructive or inquiry notice by virtue of a reference to such unrecorded instrument in a recorded instrument (or a reference to a further unrecorded instrument in such unrecorded instrument), if no claim has been made under such unrecorded instruments within the last twenty (20) years and, in each case of (i), (ii) and (iii), either such information or document is available to Acquiror from another source or there is no claim made under such document or unrecorded instrument within the past twenty (20) years prior to the date hereof;

(x) (i) lack of a division order or an operating agreement covering any Property (including portions of a Property that were formerly within a unit but which have been excluded from the unit as a result of a contraction of the unit) or (ii) failure to obtain waivers of maintenance of uniform interest, restriction on zone transfer, or similar provisions in operating agreements with respect to assignments in the applicable Company Group Member’s chain of title to the Property unless (A) the underlying provisions of such operating agreement provide that such failure voids or nullifies (automatically or at the election of the holder thereof) the assignment with respect to such asset or (B) there is an outstanding and pending, unresolved claim from a third party with respect to the failure to obtain such waiver; and

(y) defects based on or arising solely out of the failure of any Company Group Member to enter into, be party to, or be bound by, pooling provisions, a pooling agreement, production sharing agreement or other similar agreement with respect to any horizontal Well that crosses more than one Lease or tract (i) to the extent such Well has been permitted by the Texas Railroad Commission or other applicable Governmental Authority or (ii) to the extent the allocation of Hydrocarbons produced from such Well among such Lease or tracts is based upon the length of the “as drilled” horizontal wellbore open for production, the total length of the horizontal wellbore, or other methodology that reasonably attributes to each such Lease or leasehold tract its share of such production.

3.4 Allocated Values . Exhibit A and Exhibit B set forth the agreed allocation of the Unadjusted Purchase Price among the Assets. The “ Allocated Value ” for any Property equals the portion of the Unadjusted Purchase Price that is allocated to such Property on Exhibit A and Exhibit B ; provided , that for the purposes of Schedule 6.13 , “Allocated Value” shall mean the amount determined in accordance with Section 1.3(d) of Schedule 6.13 , subject to the terms and conditions of Schedule 6.13 .

 

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3.5 Environmental Assessment; Environmental Defects .

(a) From and after the date of this Agreement, Acquiror shall have the right to conduct, or cause a reputable environmental consulting or engineering firm (the “ Environmental Consultant ”), to conduct, an environmental review of Assets as provided in this Section  3.5 (the “ Environmental Review ”). Contributor shall have the right to have a representative of Contributor accompany the Acquiror during any such Environmental Review.

(b) Except as expressly provided in this Section  3.5 , Acquiror’s Environmental Review shall be limited to conducting a Phase I Environmental Site Assessment in accordance with the American Society for Testing and Materials (A.S.T.M.) Standard Practice Environmental Site Assessments: Phase I Environmental Site Assessment Process, or a similar visual evaluation of the Assets that does not involve the sampling of any environmental media or the operation of any equipment, and an environmental compliance review (each, a “ Site Assessment ). In the event that Acquiror’s Site Assessment identifies actual or potential “recognized environmental conditions” with respect to any Assets which are operated or solely owned by a Company Group Member and Acquiror reasonably believes that sampling of environmental media is necessary to prove that an Environmental Defect exists or to establish the Environmental Defect Amount, then Acquiror may request in writing that the Contributor cause the applicable Company Group Member to grant permission to Acquiror to conduct Phase II Environmental Assessments to further assess such conditions (each a “ Phase II Request ”). Each Phase II Request will state with reasonable specificity (i) the actual or potential “recognized environmental conditions” that require further investigation in order to prove that an Environmental Defect exists or to establish the Environmental Defect Amount and (ii) the proposed scope of the Phase II Environmental Assessment and Phase II Environmental Assessment plan, including a description of the activities to be conducted, and a description of the approximate location and expected timing of such activities. Acquiror shall not have the right to conduct any activities set forth in such Phase II Environmental Assessment plan until such time that Contributor has caused the applicable Company Group Member to approve such plan in writing. If requested by Contributor, Acquiror shall modify its Phase II Environmental Assessment Plan to address Contributor’s reasonable comments, which Contributor will promptly provide following receipt of the applicable Phase II Request. Contributor shall not unreasonably withhold, condition or delay its approval of any of any Acquiror Phase II Request and upon such approval shall cause the applicable Company Group Member to grant Acquiror permission and access to conduct such Phase II Environmental Assessment. Any such approved Phase II Environmental Assessment plan shall be conducted by a reputable environmental consulting or engineering firm, and in a safe and prudent manner. Contributor shall have the right to have its representatives witness all on-site activities set forth in the applicable Phase II Environmental Assessment plan and split any samples collected in connection therewith.

(c) Contributor shall, and shall cause each Company Group Member, to use commercially reasonable efforts to obtain permission from the operator of each Property for Acquiror or the Environmental Consultant to conduct the Environmental Review. If obtained prior to Closing, Acquiror shall provide copies of any final environmental reports generated by the Environmental Consultant to Contributor promptly after receipt thereby by Acquiror. Except (i) as may be necessary for, or permitted pursuant to, the exercise of the rights and fulfillment of the obligations of a Party under this Agreement, (ii) as may be required by applicable Law, or

 

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(iii) for information which is or becomes public knowledge through no fault of the Person against whom this sentence is sought to be enforced, Acquiror and Contributor and their respective Affiliates shall maintain, and shall cause their respective officers, directors, employees, contractors, consultants (including the Environmental Consultant), and other advisors to maintain, all information, reports (whether interim, draft, final, or otherwise), data, work product, and other matters obtained or generated from or attributable to the Environmental Review (the “ Environmental Information ”) strictly confidential, and shall not disclose all or any portion of the Environmental Information to any third Person without the consent of Acquiror or Contributor, as applicable, which consent shall not be unreasonably withheld, conditioned or delayed. Each Party shall be responsible for the compliance of its Affiliates, and its and their respective officers, directors, employees, contractors, consultants (including the Environmental Consultant), and other advisors with the immediately preceding sentence.

(d) As used in this Agreement, the term “ Environmental Defect ” means (i) any condition, matter, obligation, circumstance (in each case, whether or not disclosed to Acquiror prior to the date of this Agreement) with respect to the Assets that constitutes a violation of Environmental Law, or (ii) the existence of any environmental pollution, contamination, degradation, damage or injury to the environment where remedial or corrective action is presently required (or if known, would be presently required) under applicable Environmental Laws

3.6 Notice of Title Defects, Environmental Defects and Title Benefits .

(a) To assert a claim for or with respect to a Title Defect, Acquiror must deliver a defect claim notice or notices to Contributor on or before 5:00 p.m. local time in Houston, Texas on or before April 8, 2017 (the “ Defect Claim Date ”); provided , that such time period shall be extended with respect to New Properties in accordance with Schedule 6.13 . Each such notice shall be in writing and shall include:

(i) a description of the alleged Title Defect(s);

(ii) the Property or Properties affected (each, a “ Title Defect Property ”);

(iii) the Allocated Values of the Property or Properties subject to the alleged Title Defect(s);

(iv) such supporting documentation as is reasonably available to Acquiror and is reasonably necessary for Contributor (as well as any attorney or examiner hired by Contributor) to verify the existence of the alleged Title Defect(s); and

(v) Acquiror’s good faith estimate of the Title Defect Amount for each alleged Title Defect and the computations and information upon which Acquiror’s estimate is based.

 

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SUBJECT TO THE RIGHTS OF ACQUIROR PURSUANT TO THIS ARTICLE  3 AND UNDER (OR WITH RESPECT TO) ARTICLE  4 , ARTICLE  6 , ARTICLE  11 , UNDER THE CERTIFICATE TO BE DELIVERED BY CONTRIBUTOR AT CLOSING PURSUANT TO SECTION  8.2(c) , PURSUANT TO SCHEDULE 6.13 , AND THE DEFECT ESCROW AGREEMENT, ACQUIROR SHALL BE DEEMED TO HAVE WAIVED AND RELEASED ANY AND ALL TITLE DEFECTS AND ALL OTHER DEFICIENCIES OR DEFECTS IN THE COMPANY GROUP’S TITLE TO THE PROPERTIES FOR WHICH THE COMPANY GROUP HAS NOT RECEIVED, ON OR BEFORE THE DEFECT CLAIM DATE, A VALID TITLE DEFECT CLAIM NOTICE THAT SATISFIES ALL OF THE CONDITIONS AND REQUIREMENTS IN THIS SECTION  3.6(A) .

(b) (1) To assert a claim for or with respect to a Title Benefit, Contributor shall have the right to deliver to Acquiror, as soon as practicable, but in any case on or before the Defect Claim Date, and (2) in the event Acquiror discovers any Title Benefit on or prior to the Defect Claim Date, Acquiror shall, as soon as practicable, but in any case on or before the Defect Claim Date, deliver to Contributor, in the case of (1) or (2) a written benefit claim notice including:

(i) a description of the Title Benefit(s);

(ii) the Property or Properties affected (each, a “ Title Benefit Property ”);

(iii) the Allocated Values of the Property or Properties subject to such Title Benefit;

(iv) such supporting documentation as is reasonably necessary for Acquiror (as well as any attorney or examiner hired by Acquiror), as applicable, to verify the existence of the alleged Title Benefit(s); and

(v) Contributor’s or Acquiror’s, as applicable, good faith estimate of the Title Benefit Amount for each alleged Title Benefit, and the computations and information upon which Contributor’s estimate is based.

SUBJECT TO THE RIGHTS OF CONTRIBUTOR PURSUANT TO THIS ARTICLE  3 AND SCHEDULE 6.13 , CONTRIBUTOR SHALL BE DEEMED TO HAVE WAIVED ALL TITLE BENEFITS OF WHICH ACQUIROR HAS NOT RECEIVED ON OR BEFORE THE DEFECT CLAIM DATE, A VALID TITLE BENEFIT CLAIM NOTICE THAT SATISFIES THE CONDITIONS AND REQUIREMENTS IN THIS SECTION  3.6(B) , EXCEPT WITH RESPECT TO ANY TITLE BENEFIT FOR WHICH ACQUIROR HAS FAILED TO PROVIDE A NOTICE IN BREACH OF THIS SECTION  3.6(B) .

(c) To assert a claim for or with respect to an Environmental Defect, Acquiror must deliver a defect claim notice or notices to Contributor on or before the Defect Claim Date. Each such notice shall be in writing and shall include:

(i) a description of the alleged Environmental Defect(s);

 

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(ii) the Property or Properties affected (each, an “ Environmental Defect Property ”);

(iii) such supporting documentation as is reasonably available to Acquiror and is reasonably necessary for Contributor (as well as any attorney or examiner hired by Contributor) to verify the existence of the alleged Environmental Defect(s); and

(iv) Acquiror’s good faith estimate of the Environmental Defect Amount for each alleged Environmental Defect and the computations and information upon which Acquiror’s estimate is based.

SUBJECT TO THE RIGHTS OF ACQUIROR PURSUANT TO THIS ARTICLE  3 AND UNDER (OR WITH RESPECT TO) ARTICLE  4 , ARTICLE  6 , ARTICLE  11 , UNDER THE CERTIFICATE TO BE DELIVERED BY CONTRIBUTOR AT CLOSING PURSUANT TO SECTION  8.2(C) , PURSUANT TO SCHEDULE 6.13 , AND THE DEFECT ESCROW AGREEMENT, ACQUIROR SHALL BE DEEMED TO HAVE WAIVED AND RELEASED ANY AND ALL ENVIRONMENTAL DEFECTS WITH RESPECT TO THE PROPERTIES FOR WHICH THE COMPANY GROUP HAS NOT RECEIVED, ON OR BEFORE THE DEFECT CLAIM DATE, A VALID ENVIRONMENTAL DEFECT CLAIM NOTICE THAT SATISFIES ALL OF THE CONDITIONS AND REQUIREMENTS IN THIS SECTION  3.6(C) .

(d) Acquiror agrees to use reasonable good-faith efforts to provide Contributor with periodic (but in no event less frequently than before 5:00 p.m. local time in Houston, Texas on Friday of each week prior to the Defect Claim Date) updates concerning the progress of Acquiror’s title and environmental due diligence prior to the Defect Claim Date (including any potential Title Defects, Title Benefits or Environmental Defects discovered by Acquiror), which updates shall be in writing and shall be preliminary in nature.

3.7 Cure .

(a) Contributor shall have the right, but not the obligation, to attempt, at Contributor’s sole cost, risk, and expense, to cure or remove, on or before one hundred and twenty (120) days after the Closing Date (the “ Cure Date ”), any alleged Title Defects or Environmental Defects of which Contributor has been advised by Acquiror pursuant to Section  3.6(a) or Section  3.6(c) if Contributor provides written notice to Acquiror on or before the Closing Date of its intent to cure such alleged Title Defects or Environmental Defects. With respect to any Title Defect or Environmental Defect that Contributor has elected to cure pursuant to this Section  3.7(a) , the Title Defect Amounts or Environmental Defect Amounts with respect to such Title Defects and Environmental Defects shall be addressed as provided in Section  3.8(c) for purposes of Closing and thereafter any adjustment required under Section  3.8(a) with respect thereto shall be made pursuant to Section  3.8(f) . The election by Contributor to cure one or more such alleged Title Defects or Environmental Defects shall not affect the rights and obligations of the Parties under Section  3.10 with respect to dispute resolution. Contributor’s election to cure an alleged Title Defect or Environmental Defect shall not constitute a waiver of any of the rights of Contributor pursuant to this Article  3 , including Contributor’s right to dispute the existence, nature, or value of such Title Defect or Environmental Defect.

 

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(b) With respect to any alleged Title Defect or Environmental Defect which Contributor has elected to cure pursuant to Section  3.7(a) above, subject to the determination by the Title Arbitrator or Environmental Arbitrator, as applicable, of the existence or Title Defect Amount or Environmental Defect Amount with respect to such a Title Defect or Environmental Defect, as applicable, to the extent any such Title Defect or Environmental Defect is cured by Contributor on or before the Cure Date, the amount of any previous deduction from the Unadjusted Purchase Price for such Title Defect or Environmental Defect shall be addressed as provided in Section  3.8(f) .

(c) Any dispute relating to whether and to what extent a Title Defect or Environmental Defect has been cured shall be resolved as set forth in Section  3.10 , except that any such matter shall be submitted to the Title Arbitrator or Environmental Arbitrator, as applicable, on or before ten (10) Business Days after the Cure Date; provided , however , that any prior or concurrent determination by a Title Arbitrator or Environmental Arbitrator with respect to Title Defects or Environmental Defects (or factual or legal matters relating thereto, even if determined in connection with the resolution of an otherwise unrelated dispute) which Contributor has elected to cure pursuant to this Section  3.7 shall be binding on the Parties with respect to such Title Defect or Environmental Defect (or factual or legal matters relating thereto, even if determined in connection with the resolution of an otherwise unrelated dispute).

3.8 Adjustment for Title Defects, Title Benefits and Environmental Defects .

(a) With respect to each Property affected by Title Defects or Environmental Defects reported under Section  3.6(a) or Section  3.6(c) , the Unadjusted Purchase Price shall be reduced by (i) in the case of a Title Defect, an amount (the “ Title Defect Amount ”) equal to the reduction in the Allocated Value for the Properties affected thereby caused by such Title Defect, as determined prior to Closing pursuant to Section  3.9(a) , and (ii) in the case of an Environmental Defect, an amount (the “ Environmental Defect Amount ”) determined pursuant to Section  3.9(c) .

(b) With respect to each Property affected by Title Benefits reported under Section  3.6(b) , the amount by which the Unadjusted Purchase Price shall be reduced on account of Title Defects shall be offset by an amount (the “ Title Benefit Amount ”) equal to the increase in the Allocated Value for such Property caused by such Title Benefit, as determined pursuant to Section  3.9(b) .

(c) Contributor and Acquiror shall attempt to agree in writing upon all the existence of any Title Defects, Title Benefits or Environmental Defects reported pursuant to Section  3.6(a) , Section  3.6(b) or Section  3.6(c) above, as applicable, and any corresponding Title Defect Amounts, Title Benefit Amounts and Environmental Defect Amounts on or before the Closing Date. If Contributor and Acquiror are unable to agree in writing by the Closing Date, then, subject to Section  3.7 , the Title Defects, Title Benefits and Environmental Defects reported pursuant to Section  3.6(a) , Section  3.6(b) and Section  3.6(c) , as applicable, and any corresponding Title Defect Amounts, Title Benefit Amounts and Environmental Defect Amounts which are then in dispute (each a “ Disputed Matter ”) shall be exclusively and finally resolved by arbitration pursuant to Section  3.10 .

 

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(d) At Closing, the Unadjusted Purchase Price shall be adjusted by reducing both the Cash Purchase Price and the Unit Purchase Price pro rata based on the proportions that each bear to the total Unadjusted Purchase Price, (i) in accordance with Section  3.8(a) with respect to any Title Defects or Environmental Defects which (A) Contributor has not elected to cure pursuant to Section  3.7(a) and (B) which are not Disputed Matters and (ii) in accordance with Section  3.8(b) with respect to any Title Benefits which are not Disputed Matters.

(e) At Closing, the Cash Purchase Price and the Unit Purchase Price shall be reduced by an amount equal to (x) the sum of all Title Defect Amounts and Environmental Defect Amounts (as asserted in good faith by Acquiror in the applicable Title Defect notices or Environmental Defect notices provided in accordance with Section  3.6(a) or Section  3.6(c) , as applicable) related to (i) any Title Defects or Environmental Defects which Contributor elects to cure pursuant to Section  3.7(a) or (ii) which are Disputed Matters less (y) the sum of all Title Benefit Amounts (as asserted in good faith by Contributor in the applicable Title Benefit notices provided in accordance with Section  3.6(b) ) related to any Title Benefits which are Disputed Matters ((x) minus (y), the “ Defect Escrow Amount ”), with such reduction to be made to the Cash Purchase Price (the amount by which the Cash Purchase Price is so reduced, the “ Defect Escrow Cash Amount ”) and the Unit Purchase Price (the amount by which the Unit Purchase Price is so reduced, the “ Defect Escrow Unit Amount ” and, the Defect Escrow Unit Amount divided by the Per Share Value, the “ Escrowed Defect Units ”) pro rata based on the proportions that each bears to the total Unadjusted Purchase Price. At the Closing, Acquiror shall deposit the Defect Escrow Cash Amount and the Escrowed Defect Units (and a corresponding number of shares of Class B Common Stock) into an escrow account established with the Escrow Agent (the “ Defect Escrow Account ”). The Escrowed Defect Units (and the corresponding number of shares of Class B Common Stock) to be deposited into the Defect Escrow Account will be issued in the name of the Unit Recipients, whether in book-entry or certificated form, with each Unit Recipient being issued such Unit Recipient’s Pro Rata Share of the Escrowed Defect Units (and a corresponding number of shares of Class B Common Stock). The Acquiror and Contributor Representative shall, at the Closing, enter into an escrow agreement (the “ Defect Escrow Agreement ”) with the Escrow Agent an escrow agreement governing the Defect Escrow Account, which Defect Escrow Agreement shall be in customary form (which the Parties agree shall provide for the prompt disbursement from the escrow account to the registered holders of Escrowed Defect Units any tax distributions made in respect of such Escrowed Defect Units pursuant Section 6.2 of the A&R LLC Agreement) and shall contain terms and provisions consistent with this Section  3.8 ; provided, howeve r, that if the such Parties are unable to enter into any such Defect Escrow Agreement or otherwise deposit the Defect Escrow Cash Amount and Escrowed Defect Units into the Defect Escrow Account, then the Parties shall provide for appropriate alternative arrangements to give effect to the provisions of this Section  3.8 . The Escrowed Defect Units and Defect Escrow Cash Amount shall be held and disbursed in accordance with the terms of this Article  3 and the Defect Escrow Agreement pending the curing or resolution of the applicable Title Defects, Environmental Defects or Title Benefits. Each disbursement of Escrowed Defect Units pursuant to this Section  3.8 and the Defect Escrow Agreement shall be accompanied by a disbursement of a corresponding number of shares of Class B Common Stock. Whenever any disbursement of Escrowed Defect Units is made, such disbursement shall be comprised of Escrowed Defect Units (and the corresponding number of shares of Class B Common Stock) registered in the name of all Unit Recipients, with each Unit Recipient bearing or receiving, as applicable, its Pro Rata Share of such disbursement.

 

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Notwithstanding anything herein to the contrary, no fractional Acquiror Units or fractional shares of Common Stock shall be disbursed from the Defect Escrow Account, and, to the extent that any such fractional security would be required to be so disbursed but for this sentence, such fractional security shall be rounded up or down to the nearest whole number of the applicable securities. For the avoidance of doubt, the Defect Escrow Account and Defect Escrow Agreement established for the Defect Escrow Amount and the Indemnity Holdback Escrow Account and Indemnity Holdback Escrow Agreement established for the Indemnity Holdback Escrow Amount shall be independent of and separate from the Deposit Escrow Account and Deposit Escrow Agreement established for the Deposit.

(f) Within ten (10) Business Days after the latter of the Cure Date or the determination of all Disputed Matters submitted to a Title Arbitrator or Environmental Arbitrator pursuant to Section  3.10(a) or Section  3.10(b) , as applicable, the Parties shall, after giving effect to the limitations provided in Section  3.9 , execute joint written instructions to the Escrow Agent instructing it to deliver (i) to Acquiror, an amount equal to (x) the sum of the Title Defect Amounts associated with (i) those Title Defects which Contributor elected to cure pursuant to Section  3.7(a) which are not Disputed Matters and which are not fully cured as provided in Section  3.7 ( provided , however , if curative efforts by Contributor mitigated an uncured Title Defect, the Title Defect Amount associated with such Title Defect shall be revised pursuant to Section  3.9(a) to take into account such curative efforts) and (ii) any Disputed Title Matters determined in favor of Acquiror by the applicable Title Arbitrator under Section  3.10 , less (y) any offsetting Title Benefits which are Disputed Title Matters and are determined in favor of Contributor by the Title Arbitrator under Section  3.10 plus (z) the sum of the Environmental Defect Amounts associated with (i) those Environmental Defects which Contributor elected to cure pursuant to Section  3.7(a) which are not Disputed Matters and which are not fully cured as provided in Section  3.7 ( provided , however , if curative efforts by Contributor mitigated an uncured Environmental Defect, the Environmental Defect Amount associated with such Environmental Defect shall be revised pursuant to Section  3.9(c) to take into account such curative efforts) and (ii) any Disputed Environmental Matters, determined in favor of Acquiror by the applicable Environmental Arbitrator under Section  3.10 , with such amount to be disbursed from the Defect Escrow Cash Amount and the Escrowed Defect Units, pro rata based on the proportions that each bears to the total value contained in the Defect Escrow Account (valuing the Escrowed Defect Units at the Per Share Value for such purpose) and any amount disbursed in Escrowed Defect Units shall be disbursed by delivering a number of Escrowed Defect Units equal to the amount of the portion of such distribution to be disbursed in Escrowed Defect Units and (ii) to Contributor, the remainder of the Defect Escrow Cash Amount and the Escrowed Defect Units. The Parties shall treat for Tax purposes, any amounts paid pursuant to this Section  3.8(f) as an adjustment to the Unadjusted Purchase Price.

3.9 Calculation of Title Defect Amounts, Title Benefit Amounts and Environmental Defect Amounts .

(a) The Title Defect Amount resulting from a Title Defect shall be determined as follows:

(i) if Acquiror and Contributor agree in writing upon the Title Defect Amount, then that amount shall be the Title Defect Amount;

 

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(ii) if the Title Defect is a lien, encumbrance or other charge which secures the payment of an undisputed liquidated amount, then the Title Defect Amount shall be the amount necessary to be paid to unconditionally remove the Title Defect from the Title Defect Property;

(iii) if the Title Defect solely represents a discrepancy between (A) the Net Revenue Interest of any Company Group Member for any Well that is a Title Defect Property and (B) the Net Revenue Interest stated therefor on Exhibit  B , and there is no discrepancy with respect to the applicable Company Group Member’s Working Interest in such Well and the Working Interest stated therefor on Exhibit  B , then the Title Defect Amount shall be the product of the Allocated Value of such Title Defect Property multiplied by a fraction, the numerator of which is the absolute amount of such Net Revenue Interest decrease and the denominator of which is the Net Revenue Interest stated on Exhibit  B for such Title Defect Property; provided , however , if the Title Defect does not affect a Title Defect Property throughout its entire productive life, the Title Defect Amount determined under this Section 3.9(a)(iii) shall be reduced to take into account the applicable time period only;

(iv) if the Title Defect solely represents a discrepancy between (A) the Net Acres of any Company Group Member for any Title Defect Property and (B) the Net Acres stated therefor on Exhibit  A , and there is no discrepancy with respect to the applicable Company Group Member’s Net Revenue Interest in such Title Defect Property and the Net Revenue Interest stated therefor on Exhibit  A , then the Title Defect Amount shall be the product of the Allocated Value of such Title Defect Property multiplied by a fraction, the numerator of which is the absolute value of the Net Acre decrease and the denominator of which is the Net Acres stated on Exhibit  A for such Title Defect Property;

(v) if the Title Defect is not of the type described in clauses (i)  through (iv) above, the Title Defect Amount shall be determined by taking into account the Allocated Value of the Title Defect Property, the portion of the Title Defect Property affected by the Title Defect, the legal effect of the Title Defect, the potential economic effect of the Title Defect over the life of the Title Defect Property, the values placed on such Title Defect by Contributor and Acquiror and such other reasonable factors as are necessary to make a proper evaluation;

(vi) if a Title Defect is reasonably capable of being cured, the Title Defect Amount shall not be greater than the reasonable cost and expense of curing such Title Defect; provided , however , that if the same Title Defect affects multiple Properties, the Title Defect Amount for such Title Defect shall include the amounts calculated as provided in this Section 3.9(a) for all of the Properties affected by such Title Defect;

(vii) the Title Defect Amount with respect to each Title Defect Property shall be determined without duplication of any costs or losses included in another Title Defect Amount hereunder; and

(viii) notwithstanding anything to the contrary in this Agreement:

(A) an individual claim for a Title Defect for which a claim notice is given prior to the Defect Claim Date in accordance with Section  3.6(a) shall only generate an adjustment to the Unadjusted Purchase Price under this Article  3 if the Title Defect Amount with respect thereto exceeds Seventy-Five Thousand Dollars ($75,000);

 

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(B) except for liens, encumbrances or other charges which secure the payment of an undisputed liquidated amount owed by or on behalf of the Company Group, the aggregate Title Defect Amounts attributable to the effects of all Title Defects upon any given Property shall not exceed the Allocated Value of such Property; and

(C) there shall be no adjustment to the Unadjusted Purchase Price for Title Defects unless and until the aggregate of (w) all Title Defect Amounts which would generate an adjustment to the Unadjusted Purchase Price pursuant to Section  3.9(a)(viii)(A) , less (x) all Title Benefit Amounts that would generate an offset to Title Defect Amounts pursuant to Section 3.9(b)(vi) , plus (y) all Environmental Defect Amounts which would generate an adjustment to the Unadjusted Purchase Price pursuant to Section  3.9(c)(iv)(A) , plus (z) the amount equal to the Negative Allocated Value Adjustment Amount exceeds two and one-half percent (2.5%) of the Unadjusted Purchase Price, and then only to the extent that such aggregate amount exceeds two and one-half percent (2.5%) of the Unadjusted Purchase Price.

(b) The Title Benefit Amount resulting from a Title Benefit shall be determined as follows:

(i) if Acquiror and Contributor agree in writing upon the Title Benefit Amount, then that amount shall be the Title Benefit Amount;

(ii) if the Title Benefit solely results from (A) the Net Acres of any Company Group Member for any Title Benefit Property throughout the productive life of the affected Lease being greater than (B) the Net Acres stated therefor on Exhibit  A , and there is no discrepancy with respect to the applicable Company Group Member’s Net Revenue Interest in such Title Benefit Property and the Net Revenue Interest stated therefor on Exhibit  A , then the Title Benefit Amount shall be the product of the Allocated Value of such Title Benefit Property multiplied by a fraction, the numerator of which is the amount of the Net Acres increase and the denominator of which is the Net Acres stated on Exhibit  A for such Title Benefit Property;

(iii) if the Title Benefit solely results from (A) the Net Revenue Interest of any Company Group Member for any Well that is a Title Benefit Property being greater than (B) the Net Revenue Interest stated therefor on Exhibit  B throughout the duration of the productive life of the affected Well, and there is no discrepancy with respect to the applicable Company Group Member’s Working Interest in such Well and the Working Interest stated therefor on Exhibit  B , then the Title Benefit Amount shall be the product of the Allocated Value of such Title Defect Property multiplied by a fraction, the numerator of which is the amount of such Net Revenue Interest increase and the denominator of which is the Net Revenue Interest stated on Exhibit  B for such Title Benefit Property; and

 

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(iv) if the Title Benefit is not of the type described in clauses (i)  through (iii) above, the Title Benefit Amount shall be determined by taking into account the Allocated Value of the Title Benefit Property, the portion of the Title Benefit Property affected by the Title Benefit, the legal effect of the Title Benefit, the potential discounted economic effect of the Title Benefit over the life of the Title Benefit Property, the values placed upon the Title Benefit Property by Acquiror and Contributor and such other reasonable factors as are necessary to make a proper evaluation;

(v) the Title Benefit Amount with respect to a Title Benefit shall be determined without duplication of any costs or losses included in another Title Benefit Amount or adjustment to the Unadjusted Purchase Price; and

(vi) notwithstanding anything to the contrary in this Article  3 , an individual claim for a Title Benefit shall only generate an offset to the amount by which the Unadjusted Purchase Price shall be reduced on account of Title Defects pursuant to Section  3.8(b) if the Title Benefit Amount with respect thereto exceeds Seventy-Five Thousand Dollars ($75,000).

(c) The Environmental Defect Amount resulting from an Environmental Defect shall be determined as follows:

(i) if Acquiror and Contributor agree on the Environmental Defect Amount, that amount shall be the Environmental Defect Amount;

(ii) the Environmental Defect Amount shall include the amount required to Remediate the Environmental Defect or otherwise bring the affected Asset into compliance with Environmental Laws in the most cost-effective manner reasonably available;

(iii) the Environmental Defect Amount with respect to an Environmental Defect shall be determined on an individual Asset-by-Asset basis without duplication of any costs or losses included in another Environmental Defect Amount or adjustment to the Unadjusted Purchase Price; and

(iv) notwithstanding anything to the contrary in this Article  3 :

(A) an individual claim for an Environmental Defect shall only generate an adjustment to the Unadjusted Purchase Price if the Environmental Defect Amount with respect thereto exceeds Seventy-Five Thousand Dollars ($75,000); and

(B) there shall be no adjustment to the Unadjusted Purchase Price for Environmental Defects unless and until the aggregate of (w) all Title Defect Amounts which would generate an adjustment to the Unadjusted Purchase Price pursuant to Section  3.9(a)(viii)(A) , less (x) all Title Benefit Amounts that would generate an offset to Title Defect Amounts pursuant to Section 3.9(b)(vi) , plus (y) all Environmental Defect Amounts which would generate an adjustment to the Unadjusted Purchase Price pursuant to Section  3.9(c)(iv)(A) , plus (z) the amount equal to the absolute value of the Negative Allocated Value Adjustment Amount exceeds two and one-half percent (2.5%) of the Unadjusted Purchase Price, and then only to the extent that such aggregate amount exceeds two and one-half percent (2.5%) of the Unadjusted Purchase Price.

 

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3.10 Dispute Resolution .

(a) Except as provided in Section  3.7(c) , with respect to any Disputed Matter concerning Title Defects, Title Benefits, Title Defect Amounts and Title Benefit Amounts (“ Disputed Title Matters ”), on or before a date that is ten (10) Business Days following the Closing Date, or, with respect to Title Defects related to any New Property, on or before a date that is ten (10) Business Days following the end of the title review period attributable to such New Property as provided in Schedule 6.13 if such date is later than ten (10) Business Days following the Closing Date, in each case Contributor shall submit all remaining Disputed Title Matters to a title attorney with at least ten (10) years’ experience in oil and gas titles in the state of Texas, as selected by mutual written agreement of Acquiror and Contributor (the “ Title Arbitrator ”). If Acquiror and Contributor have not agreed upon a Person to serve as Title Arbitrator during such ten (10) Business Day period, Contributor shall, within ten (10) Business Days after the end of such initial ten (10) Business Day period, formally apply to the Houston, Texas office of the American Arbitration Association to choose the Title Arbitrator. The Title Arbitrator shall not have worked as an employee or outside counsel for any Party or its Affiliates during the five (5) year period preceding the arbitration or have any financial interest in the dispute (other than the payment of its fees as provided in this Agreement). If Contributor has not submitted such Disputed Title Matters to the Title Arbitrator or the Houston, Texas office of the American Arbitration Association, as applicable, within the relevant time period set forth above (or, with respect to Disputed Title Matters concerning Title Defects Contributor has elected to cure pursuant to Section  3.7(a) , the date set forth in Section  3.7(c) ), Contributor shall be deemed to have waived its dispute of such Disputed Title Matters.

(b) Except as provided in Section  3.7(c) , with respect to any Disputed Matter concerning Environmental Defects and Environmental Defect Amounts (“ Disputed Environmental Matters ”), on or before a date that is ten (10) Business Days following the Closing Date, Contributor shall submit all remaining Disputed Environmental Matters to a reputable environmental consultant or engineer with at least fifteen (15) years’ experience in corrective environmental action regarding oil and gas properties in the state of Texas, as selected by mutual agreement of Acquiror and Contributor (the “ Environmental Arbitrator ”). If Acquiror and Contributor have not agreed upon a Person to serve as Environmental Arbitrator during such ten (10) Business Day period, Contributor shall, within ten (10) Business Days after the end of such initial ten (10) Business Day period, formally apply to the Houston, Texas office of the American Arbitration Association to choose the Environmental Arbitrator. The Environmental Arbitrator shall not have worked as an employee, consultant, or outside counsel for any Party or its Affiliates during the five (5) year period preceding the arbitration or have any financial interest in the dispute (other than the payment of its fees as provided in this Agreement). If Contributor has not submitted such Disputed Environmental Matters to the Environmental Arbitrator or the Houston, Texas office of the American Arbitration Association, as applicable, within the relevant time period set forth above (or, with respect to Disputed Environmental Matters concerning Environmental Defects Contributor has elected to attempt to cure pursuant to Section 3.7(a) , the date set forth in Section  3.7(c) ), Contributor shall be deemed to have waived its dispute of such Disputed Environmental Matters.

 

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(c) The arbitration proceeding shall be held in Houston, Texas and shall be conducted in accordance with the Commercial Arbitration Rules of the American Arbitration Association, to the extent such rules do not conflict with the terms of this Section  3.10 . The Title Arbitrator’s or Environmental Arbitrator’s determination shall be made within forty-five (45) days after submission of the matters in dispute and shall be final and binding upon the Parties, without right of appeal. In making its determination, the Title Arbitrator or Environmental Arbitrator, as applicable, shall be bound by the provisions of this Article  3 and may consider such other matters as in the opinion of the Title Arbitrator or Environmental Arbitrator, as applicable, are necessary or helpful to make a proper determination. The Title Arbitrator and Environmental Arbitrator may consult with and engage disinterested third Persons to advise the arbitrator, including petroleum engineers. The Title Arbitrator or Environmental Arbitrator, as applicable, is only authorized to rule in favor of Contributor or Acquiror with respect to each Disputed Matter. The Title Arbitrator or Environmental Arbitrator shall act as an expert for the limited purpose of determining the specific Disputed Matter, as applicable, submitted by any Party and may not award damages, interest, or penalties to any Party with respect to any matter. Contributor and Acquiror shall each bear their own legal fees and other costs of presenting their respective cases. Acquiror and Contributor shall each bear one-half of the costs and expenses of the Title Arbitrator and Environmental Arbitrator.

3.11 Notice to Holders of Consents and Preferential Purchase Rights . Within three (3) Business Days after the Execution Date, Contributor shall prepare and send (a) notices to the holders of any required consents to assignment that are set forth on Schedule  4.7 requesting consents to the transactions contemplated by this Agreement and (b) notices to the holders of any preferential purchase rights, rights of first offer, rights of first refusal or similar rights applicable to any of the Assets that are required in connection with the transactions contemplated by this Agreement (each, a “ Preferential Purchase Right ”) that are set forth on Schedule  4.7 in compliance with the terms of such rights and requesting waivers of such rights. Acquiror shall use commercially reasonable efforts to cooperate with Contributor in seeking to obtain such consents, approvals, permissions, and waivers. Contributor shall not be obligated to make any payments or incur any liabilities in connection with obtaining such consents or such waivers.

3.12 Preferential Purchase Rights .

(a) Any Preferential Purchase Right must be exercised subject to all terms and conditions set forth in this Agreement, including the successful Closing of this Agreement pursuant to Article  8 on the dates certain set forth herein. The consideration payable under this Agreement for any particular Asset for purposes of Preferential Purchase Right notices shall be the Allocated Value for such Asset, adjusted as set forth in this Agreement.

(b) If any Preferential Purchase Right to purchase any Asset is validly exercised, whether validly or otherwise, prior to Closing, (i) Contributor shall have the right to cause the Company Group to convey such Asset to the exercising party prior to or simultaneously with the Closing on the terms and provisions set out in the applicable Preferential Purchase Right provision and there shall be no adjustment to the Unadjusted Purchase Price on account thereof and (ii) if such Asset is not conveyed prior to or simultaneously with the Closing, Acquiror shall cause the Company Group to convey such Asset to the exercising party after the Closing on the terms and provisions set out in the applicable Preferential Purchase Right provision and shall be entitled to the consideration paid by such holder.

 

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(c) Should a third Person fail to exercise or waive its Preferential Purchase Right to purchase as to any portion of the Assets prior to Closing, and the time for exercise or waiver has not yet expired by Closing or the validity of the exercise is being contested by Contributor or Acquiror, then there shall be no adjustment to the Unadjusted Purchase Price on account thereof and, if Closing occurs, Acquiror shall then cause the Company Group to comply with the terms and provisions set out in the applicable Preferential Purchase Right provision and shall be entitled to the consideration paid by such holder.

3.13 Limitations on Applicability . Subject to the rights of Acquiror pursuant to this Article  3 and under (or with respect to) Article  4 , Article  6 , Article  11 , under the certificate to be delivered by Contributor at closing pursuant to Section  8.2(c) , and pursuant to Schedule 6.13 and the Defect Escrow Agreement, Acquiror’s rights with respect to Title Defects and Environmental Defects shall terminate as of the Defect Claim Date and shall have no further force and effect thereafter; provided there shall be no termination of Acquiror’s or Contributor’s rights under Section  3.8 with respect to any Title Defect, Environmental Defect or Title Benefit claim properly reported on or before the Defect Claim Date.

ARTICLE 4

REPRESENTATIONS AND WARRANTIES OF CONTRIBUTOR PARTIES

Subject to the provisions of Sections 4.31 and 11.3 , the Contributor Parties jointly and severally represent and warrant to the Acquiror Parties the matters set out in Sections  4.1 through 4.30 .

4.1 Contributor; No Conflicts .

(a) Each Contributor Party is a limited liability company duly organized, validly existing, and in good standing under the laws of the State of Delaware. Each Contributor Party is qualified to conduct business in each state in which the business it is conducting, or the operation, ownership or leasing of its properties, makes such qualification necessary, other than where the failure to so qualify or be in good standing has not had and would not be reasonably expected to have, individually or in the aggregate, a Company Group Material Adverse Effect.

(b) Each Contributor Party has the power and authority to enter into and perform its obligations under this Agreement and each other Transaction Agreement to which it is party and to consummate the Transactions contemplated by this Agreement and such other Transaction Agreements.

(c) The execution, delivery and performance of this Agreement (and each other Transaction Agreement to which such Contributor Party is a party), and the consummation of the Transactions contemplated hereby and thereby, have been duly and validly authorized by all necessary action on the part of each Contributor Party. No vote or consent of the holders of any Interests in any Contributor Party that has not been affirmatively taken or obtained is required for the execution, delivery or performance by the Contributor Parties of this Agreement or the consummation of the transaction contemplated hereby. This Agreement has been duly executed and delivered by each Contributor Party (and at Closing each other Transaction Agreement to which a Contributor Party is a party will have been duly executed and delivered by

 

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such Contributor Party), and this Agreement constitutes the valid and binding obligations of each of the Contributor Parties, and at the Closing each other Transaction Agreement to which a Contributor Party is a party will be the valid and binding obligation of such Contributor Party, in each case enforceable in accordance with their terms except as such enforceability may be limited by applicable bankruptcy or other similar Laws affecting the rights and remedies of creditors generally as well as to general principles of equity (regardless of whether such enforceability is considered in a proceeding in equity or at law).

(d) The execution, delivery and performance of this Agreement by each Contributor Party, and the consummation of the Transactions contemplated by this Agreement, do not and will not (i) violate any provision of the Organizational Documents of any Contributor Group Member or any Company Group Member, (ii) result in a breach of or default (with due notice or lapse of time or both) or the creation of any lien or encumbrance or give rise to any right of termination, cancellation, or acceleration under any note, bond, mortgage, indenture, or other financing instrument or any Contract or other contract or agreement to which any Contributor Group Member or any Company Group Member is a party or by which any of them is bound or to which any of their assets or properties is subject, (iii) violate any judgment, order, ruling, or decree applicable to any Contributor Group Member or any Company Group Member as a party in interest, or (iv) violate any Laws applicable to any Contributor Group Member or any Company Group Member.

(e) There are no bankruptcy, reorganization, or receivership proceedings pending, being contemplated by, or, to the knowledge of the Contributor Parties, threatened against any Contributor Party or any Affiliate thereof (whether by a Contributor Party or a third Person). The Contributor Parties are not entering into this Agreement with actual intent to hinder, delay, or defraud any creditor. Immediately prior to, and immediately subsequent to, the Closing, (i) each Contributor Party will not have incurred, nor does it intend to or believe that it will incur, debts (including contingent obligations) beyond its ability to pay such debts as such debts mature or come due (taking into account the timing and amounts of cash to be received from any source, and amounts to be payable on or in respect of debts), (ii) the amount of cash available to each Contributor Party after taking into account all other anticipated uses of funds will be sufficient to pay all such amounts on or in respect of debts, when such amounts are required to be paid, and (iii) each Contributor Party will have sufficient capital with which to conduct its business.

(f) Contributor is the record and beneficial owner of, and has good and valid title to, the Company Group Interests set forth opposite Contributor’s name on Schedule 4.1 (which constitute all of the issued and outstanding Interests in the Acquired Entities), free and clear of all Encumbrances, other than restrictions on transfer that may be imposed by state or federal securities Laws or the Organizational Documents of the Acquired Entities. At the Closing, the delivery by Contributor to Acquiror of the Assignment Agreement will vest Acquiror with good and valid title to all of the Company Group Interests free and clear of all Encumbrances, other than restrictions on transfer that may be imposed by state or federal securities Laws or the Organizational Documents of the Acquired Entities and Encumbrances arising exclusively by, through or under Acquiror or its Affiliates.

 

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4.2 Litigation . Except as set forth on Schedule  4.2 : (a) there are no actions, suits, demands, investigations, administrative proceedings, or other proceedings pending before any Governmental Authority or arbitrator or, to the Contributor Parties’ knowledge, threatened in writing against any Contributor Group Member or any Company Group Member or, to the Contributor Parties’ knowledge, any applicable third Person operator with respect to the Assets, and (b) there are no actions, suits or proceedings pending before any Governmental Authority or arbitrator or, to the Contributor Parties’ knowledge, threatened in writing against any Contributor Group Member or any Company Group Member that would be reasonably expected to prevent, impair or delay materially the Contributor Parties’ ability to perform its obligations under this Agreement and the other Transaction Agreements.

4.3 Taxes . Except as set forth on Schedule  4.3 :

(a) All Tax Returns required to be filed by the Company Group have been duly and timely filed and such Tax Returns are true, correct and complete in all material respects;

(b) All Taxes due and payable by the Company Group have been paid in full;

(c) All withholding Tax requirements imposed on the Company Group have been satisfied in full;

(d) The Company Group does not have in force any waiver of any statute of limitations in respect of Taxes or any extension of time with respect to a Tax assessment or deficiency;

(e) No extension of time within which to file any Tax Return by the Company Group is currently in effect;

(f) There are no Encumbrances on any of the Assets currently existing, pending or, to the knowledge of Contributor, threatened related to any unpaid Taxes (other than for Taxes that are not yet due and payable);

(g) There are no pending or active audits or legal proceedings involving Tax matters or, to the knowledge of Contributor, threatened audits, legal proceedings or proposed deficiencies or other claims for unpaid Taxes, of the Company Group;

(h) Each Asset that is subject to property Tax has been properly listed and described on the property Tax rolls for all periods prior to and including the Closing Date and no portion of such Assets constitutes omitted property for property Tax purposes;

(i) None of the Assets of the Company Group is “tax-exempt use property” within the meaning of Section 168(h) of the Code, “tax-exempt bond financed property” within the meaning of Section 168(g)(1)(C) of the Code or properly described in Section 168(g)(1)(D) of the Code;

 

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(j) No Asset is subject to a Tax partnership agreement or is otherwise held in an arrangement requiring a partnership income Tax Return to be filed under applicable Law (a “ Tax Partnership ”);

(k) No Company Group Member has been subject to any claim made by any Governmental Authority in a jurisdiction where such Company Group Member does not file a Tax Return to the effect that such Company Group Member may be subject to Tax in that jurisdiction; and

(l) Each of Lone Star, DE Operating and Veritas is, and has been since the date of its formation, classified as an entity disregarded as separate from its owner for U.S. federal income Tax purposes pursuant to Treasury Regulation Section 301.7701-3. Novus Land Services LLC is currently classified as an entity disregarded as separate from its owner for U.S. federal income Tax purposes pursuant to Treasury Regulation Section 301.7701-3, and has been since the date of its formation classified either as a partnership or an entity disregarded as separate from its owner for U.S. federal income Tax purposes pursuant to Treasury Regulation Section 301.7701-3.

Notwithstanding any other provision of this Agreement to the contrary, except to the extent that Taxes or the Code or Treasury Regulations are explicitly referenced elsewhere, this Section  4.3 contains the sole and exclusive representations and warranties of Contributor Parties with respect to Tax matters.

4.4 Compliance with Laws . Except with respect to Environmental Laws and Tax matters, and except as disclosed on Schedule  4.4 , (a) each Company Group Member and the ownership and operation of the Assets are, and during the past two years have been, in material compliance with, and are not in material default under or in material violation of, any applicable Law, and (b) all necessary permits, licenses, approvals, consents, certificates, and other authorizations material to the ownership and operation of the business of each Company Group Member and the Assets have been obtained and maintained in full force and effect; provided, however, that, with respect to Assets that are operated by a Person other than a Contributor Group Member or Company Group Member, the representations and warranties set forth in the preceding clauses (a) and (b) are limited to the knowledge of the Contributor Parties. Except as disclosed on Schedule  4.4 , no Company Group Member has received nor, to Contributor’s knowledge, has any applicable third Person operator of the Assets received, any written notice since December 31, 2015 of a violation of or a default by such Person with respect to any Law or any decision, ruling, order or award of any Governmental Authority or arbitrator applicable to any Company Group Member or the Assets.

4.5 Contracts . Schedule  4.5 lists all Material Contracts as of the Execution Date. Neither the applicable Company Group Member, nor, to the knowledge of the Contributor Parties, any other Person, is in default under such Material Contract, or, with the passage of time, the giving of notice, or both, would be in breach or default under any such Material Contract, except as disclosed on Schedule  4.5 . Such Material Contracts are in full force and effect. Except as disclosed on Schedule  4.5 , no written notice of default or breach has been received or delivered by any Company Group Member under any such Material Contract, the resolution of which is outstanding as of the date hereof, and there are no current notices received by any

 

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Contributor Group Member or Company Group Member of the exercise of any premature termination, price redetermination, market-out, or curtailment of any such Material Contract. Prior to the date of this Agreement, Contributor has made available to Acquiror (or its representatives) true and complete copies of each such Material Contract and all amendments or modifications thereto. Part 1 of Schedule  4.5 sets forth all Contracts that contain acreage dedications, minimum volume commitments or capacity reservation fees to a gathering, transportation or other arrangement downstream of the wellhead, that cover, guaranty, dedicate or commit (a) in excess of 1,000 Net Acres (individually or in the aggregate) or (b) volumes in excess of 6.0 MMcf (or, in the case of liquids, in excess of 2,000 barrels of oil equivalent) of Hydrocarbons of the Company Group per day over a period of one month (calculated on a yearly average basis) or for a term greater than ten years. Part 2 of Schedule  4.5 sets forth all Material Contracts that are Non-Competition Agreements.

4.6 Payments for Production; Imbalances . Except as set forth on Schedule  4.6 , the Company Group is not obligated by virtue of a take-or-pay payment, advance payment, or other similar payment (other than royalties, overriding royalties, similar arrangements established in the Leases), to deliver Hydrocarbons, or proceeds from the sale thereof, attributable to the Company Group’s interest in the Properties at some future time without receiving payment therefor at or after the time of delivery. Schedule  4.6 lists all production, transportation, plant, or other imbalances with respect to production from the Properties. No imbalance constitutes all of any Company Group Member’s (or its Affiliate’s) share of ultimately recoverable reserves in any balancing area pursuant to any gas balancing agreement.

4.7 Consents, Preferential Purchase Rights, Tag-Along Rights and Drag-Along Rights . Except as set forth on Schedule  4.7 , and subject to compliance with the HSR Act, there are no Preferential Purchase Rights to purchase, consent requirements, tag-along rights, or drag-along rights which may be applicable to the Transactions contemplated by this Agreement, except for consents and approvals of Governmental Authorities that are customarily obtained after Closing (if such Governmental Authority is, pursuant to applicable Law, without discretion to refuse to grant such consent if certain specifically enumerated conditions set forth in such applicable Law are satisfied).

4.8 Liability for Brokers Fees . The Acquiror Parties will not, directly or indirectly, have any responsibility, liability, or expense as a result of undertakings or agreements of any Contributor Group Member or any Company Group Member prior to Closing for brokerage fees, finder’s fees, agent’s commissions, or other similar forms of compensation to an intermediary in connection with the negotiation, execution or delivery of this Agreement or any agreement or transaction contemplated hereby.

4.9 Wells and Equipment . Except as set forth on Schedule  4.9 :

(a) all Wells have been drilled and completed at legal locations and within the limits permitted by all applicable Leases, Contracts, and pooling or unit agreements (or, with respect to non-producing or undrilled formations and locations, are contemplated to be so drilled and completed or may be so drilled and completed if the applicable Company Group Member or the applicable operator obtains amendments, exceptions, or other variances with respect to commingling, field spacing or density Laws which the applicable Company Group Member and the applicable operator, in good faith expects to obtain);

 

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(b) no Well is subject to penalties on allowables on or after the Effective Date because of any overproduction or any other violation of Laws; and there are no Wells located on the Assets that (i) the Company Group is currently obligated by any Laws or Contract to currently plug, dismantle or abandon; or (ii) have been plugged, dismantled, or abandoned in a manner that does not comply in all material respects with Laws;

(c) all currently producing Wells and equipment used or held for use in connection with the operation of the Properties (the “ Equipment ”) are in an operable state of repair adequate to maintain normal operations in accordance with past practices, ordinary wear and tear excepted, and, without limiting the foregoing, do not contain junk, fish, or other obstructions which could reasonably be expected to materially interfere with drilling, completion; and recompletion, stimulation, or other operations on, with respect to, or affecting the Properties, and the applicable Company Group Member (or the applicable operator) has all material easements, rights of way, licenses, and authorizations from Governmental Authorities necessary to access, construct, operate, maintain, and repair the Equipment in the ordinary course of business as currently conducted and in compliance in all material respects with all applicable Laws; and

(d) The applicable Company Group Member, or an applicable operator, has title to the Equipment free and clear of liens, encumbrances, obligations, and defects, other than Permitted Encumbrances.

provided , however, that, with respect to Assets that are operated by a Person other than a Contributor Group Member or Company Group Member, the representations and warranties set forth in the preceding clauses (a), (b), (c) and (d) are limited to the knowledge of the Contributor Parties.

4.10 Non-Consent Operations . Except as set forth on Schedule  4.10 , the Company Group has not elected not to participate in any operation or activity proposed with respect to the Properties which could result in any of the Company Group’s interest in such Properties becoming subject to a penalty or forfeiture as a result of such election not to participate in such operation or activity. Schedule  4.10 contains a complete and accurate list of the status of any payout balances for each Property which is subject to a reversion or other adjustment at any level of cost recovery or Hydrocarbon production from or attributable to such Property, as of the dates shown on such schedule with respect to each Property.

4.11 Outstanding Capital Commitments . As of the date of this Agreement, there are no outstanding authorizations for expenditure which are binding on the Properties and which Contributor reasonably anticipates will individually require expenditures by any Company Group Member or its successor in interest from and after the Effective Date in excess of One Hundred Thousand Dollars ($100,000), other than as shown on Schedule  4.11 .

 

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4.12 Environmental . Except as shown on Schedule  4.12 :

(a) no Contributor Group Member or Company Group Member and, to the knowledge of the Contributor Parties, no other Person operating any of the Assets has received any written notice from any applicable Governmental Authority or third Person alleging or asserting any material Environmental Liabilities or that the Assets are in material violation of Environmental Laws or that any of the Properties require material Remediation under, Environmental Laws;

(b) to the knowledge of the Contributor Group, each Company Group Member and the Assets (and the operation thereof and the Company Group’s ownership thereof) are in material compliance with all applicable Environmental Laws;

(c) the Company Group and each Company Group Member possesses all permits, licenses, approvals, consents, certificates and other authorizations of a material nature required by Environmental Laws or by any Governmental Authority for the ownership or operation of the Assets (the “ Environmental Permits ”) and all such Environmental Permits are, and have been, maintained in full force and effect;

(d) there are no actions, suits, demands, investigations, administrative proceedings, or other proceedings pending or, to the Contributor Group’s knowledge, threatened in writing before any Governmental Authority or arbitrator against any Contributor Group Member or any Company Group Member or to which any of the Assets are subject, asserting or alleging any Environmental Liabilities with respect to the Assets;

(e) no Company Group Member has entered into, and no Company Group Member (or any Asset) is subject to, any agreements, consents, orders, decrees, judgments or other directives from any Governmental Authority that relate to the future use of any Asset and that require Remediation or a material change in the present condition or operation of any of the Assets or Properties; and

(f) to the knowledge of the Contributor Parties, there has been no Release of any Hazardous Materials at, on, under or from the Assets or operations thereof that, with notice or the passage of time or both, could reasonably be expected to result in a material violation of any Environmental Law, any material Environmental Liabilities, or a material liability or obligation to perform material Remediation, removal, response, restoration, abatement, investigation, or monitoring pursuant to Environmental Law;

provided , however, that, with respect to Assets that are operated by a Person other than a Contributor Group Member or Company Group Member, the representations and warranties set forth in the preceding clauses (b), (c), (d) and (e) are limited to the knowledge of the Contributor Parties.

Notwithstanding any other provision of this Agreement to the contrary, the representations and warranties set forth in this Section  4.12 are Contributor Parties’ sole and exclusive representations and warranties with respect to environmental matters.

 

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4.13 Hedging Transactions . No Company Group member has entered into any Hedging Transactions. Schedule 4.13 sets forth a true and complete list of all Hedging Transactions outstanding as of the Execution Date and entered into by any Contributor Group Member with respect to the Assets (such Hedging Transactions, the “ Hedging Portfolio ”), the material terms thereof (including, without limitation, the type of transaction, term, effective date, termination date, notional amounts), and the counterparty thereto. Contributor Group has delivered to Acquiror a true and correct copy of the confirmations or other agreements evidencing the Hedging Transactions included in the Hedging Portfolio. The entry into this Agreement does not, and the consummation of the transactions contemplated by this Agreement will not, constitute or otherwise give rise to an event of default, potential event of default, or termination event (however defined or described) with respect to the applicable Contributor Group Member under any Hedging Transaction (including under any master agreement with respect thereto) included in the Hedging Portfolio or otherwise give the counterparty to any such Hedging Transaction the right to designate an early termination date in respect of such Hedging Transaction.

4.14 Absence of Certain Changes . Since September 30, 2016, (a) there has not been any (i) material write-down by the Company Group in the reserves estimated for the Properties, other than write-downs resulting from depletion in the ordinary course of operation of the Properties or that result from the variance in markets or prices for Hydrocarbons produced from the Properties; (ii) material destruction, damage or loss to or affecting any of the Assets; or (iii) Company Group Material Adverse Effect or any event, condition, change, development, circumstance or set of facts that, individually or in the aggregate, would reasonably be expected to have a Company Group Material Adverse Effect, and (b) other than the purchase of 15% of the equity of Novus Land Services LLC pursuant to the Novus Purchase Agreement, the Company Group has operated its business and the Assets in the ordinary course consistent with past practice. Since December 31, 2016, there has not been any material reduction by the Company Group in the reserves estimated for the Properties, other than reductions resulting from depletion in the ordinary course of operation of the Properties or that result from the variance in markets or prices for Hydrocarbons produced from the Properties.

4.15 Records and Information . The books and records of the Company Group have been maintained in the ordinary course of business, consistent with the applicable Company Group Member’s past practice, and no Company Group Member has intentionally omitted any material information from such books and records.

4.16 Lease Payments . The applicable Company Group Member (or, to Contributor’s knowledge, the applicable operator) has timely and properly paid all accrued bonuses, delay rentals, minimum royalties, and royalties due with respect to such Company Group Member’s interest in the Leases, in each case in accordance with the Leases and applicable Law. With respect to Leases issued by any Governmental Authority, no Company Group Member has received any written notice that any Lease accounts are not current or that any payments required thereunder have not been, or by Closing will not be, paid. Schedule  4.16 contains a true, correct, and complete list of all Leases which (a) are currently held by payment of shut-in royalties, reworking operations, any substitute for production of Hydrocarbons in paying quantities, or any other means other than production of Hydrocarbons in paying quantities, and (b) will expire, terminate, or otherwise be materially impaired absent actions by or on behalf of any Company

 

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Group Member (other than continued production in paying quantities) on or before a date that is sixty (60) days after the Target Closing Date; provided, however, with respect to Properties that are operated by a Person other than a Contributor Group Member or Company Group Member, the representations and warranties set forth in the preceding clauses (a) and (b) are limited to the knowledge of the Contributor Parties.

4.17 Bonds and Letters of Credit . Schedule  4.17 lists all bonds, letters of credit, guarantees and other similar commitments held by any Company Group Member (as applicable) that are required by applicable third Persons in order for any Company Group Member to own and, if operated by any Company Group Member, operate the Properties.

4.18 Insurance . Since the Effective Date, each Company Group Member (i) has maintained insurance on the Properties of such Company Group Member in amounts required by applicable Law and in compliance with any contract which is binding on the applicable Company Group Member and (ii) has not made an election to be excluded from any coverage provided by an operator for the joint account pursuant to any operating agreement that is binding on the Properties.

4.19 Special Warranty of Title . Except for Permitted Encumbrances, the Properties are free and clear of any Title Defects arising by, through or under any Company Group Member or any Contributor Group Member (the representation set forth in this Section  4.19 , the “ Special Warranty of Title ”).

4.20 Investment Intent .

(a) Each Contributor Party (i) is an experienced and knowledgeable investor, (ii) is able to bear the economic risks of an acquisition and ownership of the Acquiror Units comprising the Unit Purchase Price, the Class B Common Stock and the Class A Common Stock issuable upon exchange thereof (collectively, the “ Acquiror Party Securities ”), (iii) is capable of evaluating (and has evaluated) the merits and risks of investing in the Acquiror Party Securities and its acquisition and ownership thereof, (iv) is an “accredited investor,” as such term is defined in Rule 501 of Regulation D promulgated under the Securities Act, (v) is acquiring the Acquiror Party Securities for its own account and not with a view to a sale, distribution or other disposition thereof in violation of the Securities Act, and the rules and regulations thereunder, any applicable blue sky Laws, or any applicable other securities Laws, and (vi) acknowledges and understands that (A) the Acquiror Party Securities have not been registered under the Securities Act in reliance on an exemption therefrom and (B) each of the Acquiror Party Securities will, upon its acquisition by such Contributor Party, be characterized as “restricted securities” under state and federal securities Laws and may not be sold, transferred, offered for sale, pledged, hypothecated, or otherwise disposed of, except pursuant to an effective registration statement under the Securities Act or pursuant to an exemption from the registration requirements of the Securities Act, and in compliance with applicable state and federal securities Laws.

 

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(b) The distribution of Acquiror Party Securities pursuant to the Liquidations will not be made in any manner or to any Person that will result in the offer and sale of the Acquiror Party Securities pursuant to this Agreement being subject to the registration and prospectus delivery requirements of the Securities Act and the rules and regulations promulgated under the Securities Act. The execution and delivery of this Agreement by the Contributor Parties and the consummation of the transactions contemplated hereby does not require the consent or vote of (nor shall any such consent or vote be sought) from any Person that is not an “accredited investor,” as such term is defined in Rule 501 of Regulation D promulgated under the Securities Act.

4.21 [Reserved] .

4.22 Company Group . Each Company Group Member (a) is a corporation, partnership or limited liability company duly organized, as the case may be, validly existing and in good standing under the Laws of its jurisdiction of incorporation or organization, (b) has all requisite power and authority to own, lease and operate its properties and to carry on its business as now being conducted, and (c) is duly qualified and in good standing to do business in each jurisdiction in which the business it is conducting, or the operation, ownership or leasing of its properties, makes such qualification necessary, other than, in the case of this clause (c), where the failure to be so qualified or be in good standing has not had and would not be reasonably expected to have, individually or in the aggregate, a Company Group Material Adverse Effect.

4.23 Capitalization . Schedule  4.23 sets forth a true and complete list that accurately reflects the issued and outstanding Company Group Interests and the record and beneficial owners thereof. All the Company Group Interests have been validly issued and are fully paid and non-assessable (except to the extent nonassessability may be affected by Section 18-607 of the Delaware LLC Act) and the Company Group Interests are not subject to, and were not issued in violation of, any preemptive rights, rights of first refusal, rights of first offer or other similar rights. There are no Interests issued or outstanding in the Acquired Entities other than the Company Group Interests set forth on Schedule  4.23 . All the Company Group Interests have been issued and granted in compliance with (i) applicable securities Laws and other applicable Law and (ii) all requirements set forth in applicable contracts and the Organizational Documents of the Acquired Entities. Schedule  4.23 sets forth a true and complete list that accurately reflects (A) all of the Interests of each Subsidiary of the Acquired Entities and (B) the record and beneficial owners thereof. All Interests of the Subsidiaries of the Acquired Entities, (x) have been validly issued and are fully paid and non-assessable, (y) have been issued and granted in compliance with applicable securities Laws and other applicable Law and all requirements set forth in applicable contracts and the Organizational Documents of such Subsidiaries and not in violation of any pre-emptive rights, rights of first refusal, rights of first offer or other similar rights and (z) are free and clear of all Encumbrances and are not subject to any preemptive rights, rights of first refusal, rights of first offer or other similar rights, other than restrictions on transfer that may be imposed by state or federal securities Laws or the Organizational Documents of such Subsidiaries. The Company Group does not own any Interests or other securities or investments in any Person, other than as set forth on Schedule  4.23 . There are no options, warrants, calls, rights (including preemptive rights), commitments or agreements to which any Company Group Member or any Contributor Group Member is a party or by which it is bound in any case obligating any Company Group Member or any Contributor Group Member to issue, deliver, sell, purchase, redeem or acquire, or cause to be issued, delivered, sold, purchased, redeemed or acquired, additional Interests or other securities in any Company Group Member or any Contributor Group Member, or obligating any Company Group Member or any Contributor

 

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Group Member to grant, extend or enter into any such option, warrant, call, right, commitment or agreement. There are not any stockholder agreements, voting trusts or other agreements to which any Company Group Member is a party or by which it is bound relating to the voting or transfer of any Company Group Interests or Interests in the Subsidiaries of the Acquired Entities, as the case may be.

4.24 Financial Statements; No Liabilities .

(a) Contributor delivered to Acquiror Parent copies of (i) the audited balance sheet of Contributor as of December 31, 2015 and 2014 and audited income statements, statements of cash flows and members’ equity of Contributor for the fiscal years ended December 31, 2014 and 2015 and (ii) the unaudited interim financial statements of Contributor at September 30, 2016 and for the nine (9) months then ended (collectively, the “ Contributor Financial Statements ”). Except as set forth on Schedule 4.24 , each of the Contributor Financial Statements has been prepared in accordance with GAAP consistently applied by Contributor and presents fairly in all material respects the financial position, results of operations and cash flows of Contributor as at the dates and for the periods indicated therein, except that the Contributor Financial Statements for the nine (9) month period ended September 30, 2016 are subject to normal year-end adjustments.

(b) There are no liabilities of or with respect to the Company Group that would be required by GAAP to be reserved, reflected, or otherwise disclosed on a consolidated balance sheet of Contributor other than (A) liabilities reserved, reflected, or otherwise disclosed in the consolidated balance sheet of Contributor as of September 30, 2016 (including the notes thereto) included in the Contributor Financial Statements, (B) liabilities incurred in the ordinary course of business consistent with past practice since September 30, 2016, or (C) liabilities that would not reasonably be expected to have a Company Group Material Adverse Effect.

4.25 Indebtedness . At the Execution Date, the Company Group has no Indebtedness other than guarantees under the Contributor RBL. At Closing, the Company Group will not have any Indebtedness.

4.26 Employee Benefit Matters .

(a) No Company Group Member sponsors, maintains, contributes to or has any obligation to contribute to any Employee Benefit Plans. No Company Group Member has, nor following the Closing will have, any material liabilities or other material obligations under or in respect of any Contributor Benefit Plan. No event has occurred and no condition exists that could reasonably be expected to subject any Company Group Member to any material liability relating to an Employee Benefit Plan.

(b) No Company Group Member will, as a result of the Transactions, be obligated to make a payment to an individual that would reasonably be expected to be a “parachute payment” to a “disqualified individual” as those terms are defined in Section 280G of the Code without regard to whether such payment is reasonable compensation for personal services performed or to be performed in the future.

 

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4.27 Employment and Labor Matters .

(a) No Company Group Member has any employees on its payroll.

(b) Except as set forth in Schedule 4.27 , no Available Employees’ employment with Contributor or any of its Affiliates is subject to the terms of any collective bargaining Contract or other agreement or understanding with a labor union or labor organization (nor is any such agreement or contract being negotiated by or on behalf of any Company Group Member) and there are no unfair labor practice or labor arbitration proceedings pending or threatened in writing against Contributor or its Affiliates with respect to any Available Employees. To the knowledge of Contributor, there are no labor union organizing activities or labor union demands for recognition or certification, in each case, with respect to any Available Employees.

(c) With respect to the Available Employees, (i) there is no labor strike or labor dispute, unfair labor charge or complaint, slow-down, lockout, work stoppage or other labor difficulty pending or to the knowledge of Contributor threatened in writing against Contributor or its Affiliates, and (ii) neither Contributor nor any of its Affiliates is a party to, or otherwise bound by, any judgment, order, decision or award by a Governmental Authority or consent decree with any Governmental Authority relating to employment practices with respect to Available Employees.

(d) With respect to the Available Employees, Contributor and its Affiliates are and since January 1, 2016 have been in material compliance in all respects with all applicable Laws respecting labor, employment and fair employment practices, including all Laws respecting terms and conditions of employment, health and safety, wages and hours, overtime, child labor, immigration, employment discrimination, disability rights or benefits, equal opportunity, plant closures and layoffs, affirmative action, workers’ compensation, employee leave issues, labor relations, and unemployment insurance.

(e) Except as set forth on Schedule 4.27 , with respect to the Available Employees, the execution of this Agreement and the consummation of the Transactions will not result in any breach of, or payments under, any collective bargaining agreement, employment agreement, consulting agreement or any other labor-related agreement to which Contributor or its Affiliates are a party.

4.28 Intellectual Property .

(a) Except as set forth in Schedule 4.28(a) , no material registrations or applications for registration are included in any Intellectual Property Rights held by the Company Group. The Company Group owns, licenses or otherwise has a valid right to use, free and clear of all Encumbrances (other than Permitted Encumbrances or non-exclusive licenses granted by the Company Group in the ordinary course of business), all material Intellectual Property Rights necessary to conduct the business of the Company Group as currently conducted.

(b) To the Contributor Parties’ knowledge, the conduct of the business of the Company Group as currently conducted has not infringed or misappropriated any Intellectual Property Right of any other Person in any material respect.

 

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(c) The consummation of the transactions contemplated hereby will not result in the loss or impairment of any material right of the Company Group to own, use, practice or exploit any Intellectual Property Rights held by or licensed to the Company Group (excluding licenses for commercially available, “off-the-shelf” software) and used in the business of the Company Group as currently conducted.

4.29 Related Party Transactions . Except as set forth in Schedule 4.29 , there is no contract, agreement or arrangement between any Company Group Member, on the one hand, and any Contributor Group Member, any of their respective Affiliates (other than the Company Group Members) or any officer, director, manager or employee of any Contributor Group Member, any of their respective Affiliates, any Company Group Member or any immediate family member or Affiliate of any such officer, director, manager or employee, on the other hand (each such contract, agreement or arrangement, an “ Affiliate Contract ”).

4.30 Change of Control . No Contract contains a change of control provision that would become operative as a result of the Transactions contemplated by this Agreement.

4.31 Limitations .

(a) EXCEPT AS AND TO THE EXTENT EXPRESSLY REPRESENTED OTHERWISE IN THIS ARTICLE  4 , IN SECTION  3.1 , OR IN THE CERTIFICATE OF CONTRIBUTOR TO BE DELIVERED AT CLOSING PURSUANT TO SECTION  8.2(c) , CONTRIBUTOR EXPRESSLY DISCLAIMS ANY REPRESENTATION OR WARRANTY, EXPRESS, IMPLIED, OR STATUTORY, AS TO (I) TITLE TO ANY OF THE ASSETS, (II) THE CONTENTS, CHARACTER OR NATURE OF ANY DESCRIPTIVE MEMORANDUM, OR ANY REPORT OF ANY PETROLEUM ENGINEERING CONSULTANT OF CONTRIBUTOR, OR ANY GEOLOGICAL OR SEISMIC DATA OR INTERPRETATION, RELATING TO THE ASSETS, (III) THE QUANTITY, QUALITY OR RECOVERABILITY OF PETROLEUM SUBSTANCES IN OR FROM THE ASSETS, (IV) THE ABILITY OF THE PROPERTIES TO PRODUCE HYDROCARBONS, INCLUDING PRODUCTION RATES, DECLINE RATES, AND RECOMPLETION OPPORTUNITIES; (V) ANY ESTIMATES OF THE VALUE OF THE ASSETS OR FUTURE REVENUES GENERATED BY THE ASSETS, (VI) INFRINGEMENT OF ANY INTELLECTUAL PROPERTY RIGHT, (VII) ANY OTHER MATERIALS OR INFORMATION THAT MAY HAVE BEEN MADE AVAILABLE OR COMMUNICATED TO ACQUIROR OR ITS AFFILIATES, OR ITS OR THEIR EMPLOYEES, AGENTS, CONSULTANTS, REPRESENTATIVES OR ADVISORS IN CONNECTION WITH THE TRANSACTIONS CONTEMPLATED BY THIS AGREEMENT OR ANY DISCUSSION OR PRESENTATION RELATING THERETO, AND FURTHER DISCLAIMS ANY REPRESENTATION OR WARRANTY, EXPRESS, IMPLIED, OR STATUTORY, OF MERCHANTABILITY, FITNESS FOR A PARTICULAR PURPOSE OR CONFORMITY TO MODELS OR SAMPLES OF MATERIALS OR ANY EQUIPMENT, IT BEING EXPRESSLY UNDERSTOOD AND AGREED BY THE PARTIES THAT, EXCEPT AS PROVIDED TO THE CONTRARY IN THIS AGREEMENT, THE ASSETS ARE BEING TRANSFERRED “AS IS, WHERE IS,” WITH ALL FAULTS AND DEFECTS.

 

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(b) Acquiror acknowledges that Equipment and sites included in the Assets may contain naturally occurring radioactive material (“ NORM ”). NORM may affix or attach itself to the inside of wells, materials, and equipment as scale, or in other forms. The wells, materials, and equipment located on the Properties or included in the Assets may contain NORM. NORM may have come into contact with various environmental media, including water, soils, or sediment. Notwithstanding anything to the contrary in this Section  4.31(b) or elsewhere in this Agreement, Contributor makes no, and hereby disclaims any, representation or warranty, express or implied, with respect to the presence or absence of NORM in or on the Properties or Equipment other than in quantities which are in compliance with applicable Law and which are typical for oilfield operations in the areas in which the Assets are located.

(c) As used in this Agreement, except as otherwise expressly stated, “to the knowledge of the Contributor Parties”, “to the Contributor Parties’ knowledge”, or phrases of similar import mean to the actual knowledge (after reasonable inquiry into the matters in question, including inquiry of the managers of the Contributor Group Members or the Company Group Members with direct supervisory responsibility) of Cody C. Campbell, John A. Sellers and Kyle Kulig.

ARTICLE 5

REPRESENTATIONS AND WARRANTIES OF ACQUIROR PARTIES

Each of Acquiror Parties jointly and severally represents and warrants to Contributor the following:

5.1 Existence and Qualification . Each Acquiror Party is a corporation or limited liability company, as the case may be, that is duly organized or formed, validly existing and in good standing under the Laws of the State of Delaware and is duly qualified to carry on its business in states where the nature of its business or the ownership or leasing of its properties makes such qualification necessary, except where the failure to be so qualified has not had or would not be reasonably expected to have, individually or in the aggregate, an Acquiror Material Adverse Effect.

5.2 Power . Each Acquiror Party has the corporate or limited liability company, as the case may be, power to enter into and perform its obligations under this Agreement and each other Transaction Agreement to which it is a party and to consummate the Transactions contemplated by this Agreement.

5.3 Authorization and Enforceability . The execution, delivery and performance of this Agreement and each other Transaction Agreement to which it is a party, and the consummation of the Transactions contemplated hereby and thereby, have been duly and validly authorized by all necessary action on the part of each Acquiror Party. This Agreement has been duly executed and delivered by each Acquiror Party (and at Closing each other Transaction Agreement to which an Acquiror Party is a party will have been duly executed and delivered by such Acquiror Party), and this Agreement constitutes the valid and binding obligations of each Acquiror Party, and at Closing each other Transaction Agreement to which an Acquiror Party is a party will be the valid and binding obligation of such Acquiror Party, enforceable in accordance with their terms except as such enforceability may be limited by applicable bankruptcy or other similar Laws affecting the rights and remedies of creditors generally as well as to general principles of equity (regardless of whether such enforceability is considered in a proceeding in equity or at law).

 

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5.4 No Conflicts . Except as required under the HSR Act, filings that will be made pursuant to the rules and regulations of the NYSE and filings pursuant to applicable federal and state securities Laws and assuming the receipt of the Credit Agreement Consent and the execution and delivery of the A&R Registration Rights Agreement by the parties thereto, the execution, delivery and performance of this Agreement by each Acquiror Party, and the consummation of the Transactions contemplated by this Agreement, will not (a) violate any provision of the Organizational Documents of the Acquiror Parties, (b) result in a material default (with due notice or lapse of time or both) or the creation of any lien or encumbrance or give rise to any right of termination, cancellation or acceleration under any material note, bond, mortgage, indenture, or other financing instrument to which any Acquiror Group Member is a party or by which it is bound, (c) violate any judgment, order, ruling, or regulation applicable to any Acquiror Group Member as a party in interest, or (d) violate any Law applicable to any Acquiror Group Member, except any matters described in clauses (b) , (c) , or (d)  above which would not have an Acquiror Material Adverse Effect.

5.5 Consents, Approvals or Waivers . Except as required under (i) the HSR Act, (ii) filings that will be made pursuant to the rules and regulations of the NYSE and filings pursuant to applicable federal and state securities Laws, (iii) that certain Credit Agreement, dated as of October 28, 2016, by and among Acquiror Parent and Acquiror, Wells Fargo Bank, National Association, as administrative agent, JPMorgan Chase Bank, N.A., as syndication agent, BMO Harris Bank, N.A., as documentation agent, and the other lenders party thereto, as amended from time to time (the “ Credit Agreement ”) or (iv) the Existing Registration Rights Agreement, the execution, delivery and performance of this Agreement by Acquiror Parties will not be subject to any consent, approval or waiver from any Governmental Authority or other third Person except for consents and approvals of Governmental Authorities that are customarily obtained after Closing (if, such Governmental Authority is, pursuant to applicable Law, without discretion to refuse to grant such consent if certain conditions set forth in such applicable Law are satisfied).

5.6 Litigation .

(a) Except as to specific matters disclosed in the SEC Documents filed or furnished on or after January 1, 2016 and prior to the Execution Date (excluding any disclosures included in any “risk factor” section of such SEC Documents or any other disclosures in such SEC Documents to the extent they are predictive or forward looking and general in nature), there are no actions, suits or proceedings pending, or to Acquiror Parties’ knowledge, threatened in writing before any Governmental Authority or arbitrator against either Acquiror Party or any Affiliate of an Acquiror Party that have had or would be reasonably expected to have, individually or in the aggregate, an Acquiror Material Adverse Effect under clause (a) of the definition of Acquiror Material Adverse Effect.

 

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(b) There are no actions, suits or proceedings pending, or to Acquiror Parties’ knowledge, threatened in writing before any Governmental Authority or arbitrator against either Acquiror Party or any Affiliate of an Acquiror Party that have had or would be reasonably expected to have, individually or in the aggregate, an Acquiror Material Adverse Effect under clause (b) of the definition of Acquiror Material Adverse Effect.

5.7 Financing . The Acquiror Parties (a) have sufficient (i) cash on hand (in United States Dollars), (ii) available lines of credit under Acquiror Parties’ existing credit facilities and (iii) access to the capital markets to enable Acquiror to fund the Deposit on the Execution Date and (b) will have at Closing all amounts required to pay the Cash Closing Payment on the Closing Date to Contributor.

5.8 Investment Intent . Acquiror is acquiring the Company Group Interests for its own account and not with a view to their sale or distribution in violation of the Securities Act of 1933, as amended, the rules and regulations thereunder, any applicable state blue sky Laws, or any other applicable securities Laws.

5.9 Investment Company . Neither Acquiror Party is now, and immediately after the issuance and sale of the Acquiror Units comprising the Unit Purchase Price and the Class B Common Stock will not be, required to register as an “investment company” or a company “controlled by” an entity required to register as an “investment company” within the meaning of the Investment Company Act of 1940, as amended.

5.10 Independent Investigation . Acquiror is (or its advisors are) experienced and knowledgeable in the oil and gas business and aware of the risks of that business. Acquiror acknowledges and affirms that (a) it has completed such independent investigation, verification, analysis and evaluation of the Assets and has made all such reviews and inspections of the Assets as it has deemed necessary or appropriate to enter into this Agreement, and (b) if Closing occurs, it will be deemed to have completed its independent investigation, verification, analysis, and evaluation of the Assets and made all such reviews and inspections of the Assets as it will have deemed necessary or appropriate to consummate the Transactions contemplated hereby.

5.11 Liability for Brokers Fees . The Contributor Parties will not, directly or indirectly, have any responsibility, liability, or expense as a result of undertakings or agreements of Acquiror Parties for brokerage fees, finder’s fees, agent’s commissions, or other similar forms of compensation to an intermediary in connection with the negotiation, execution, or delivery of this Agreement or any agreement or Transaction contemplated hereby.

5.12 Bankruptcy . There are no bankruptcy, reorganization, or receivership proceedings pending, being contemplated by, or, to the knowledge of Acquiror Parties, threatened against either Acquiror Party or any Affiliate of Acquiror Parties (whether by an Acquiror Party or a third Person). Immediately prior to, and immediately subsequent to, the Closing, (a) neither Acquiror Party will have incurred, nor does it intend to or believe that it will incur, debts (including contingent obligations) beyond its ability to pay such debts as such debts mature or come due (taking into account the timing and amounts of cash to be received from any source, and amounts to be payable on or in respect of debts), (b) the amount of cash available to each Acquiror Party after taking into account all other anticipated uses of funds is anticipated to be sufficient to pay all such amounts on or in respect of debts, when such amounts are required to be paid, and (c) each Acquiror Party will have sufficient capital with which to conduct its business.

 

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5.13 Valid Issuance . At Closing, the Acquiror Units to be issued to Contributor as the Unit Purchase Price will be duly authorized, validly issued, fully paid and non-assessable (except to the extent nonassessability may be affected by Section 18-607 of the Delaware LLC Act) and the Acquiror Units will be free of any Encumbrances, other than restrictions on transfer under federal and state securities Laws, as provided in this Agreement, the Registration Rights and Lock-Up Agreement and the LLC Agreement and Encumbrances arising exclusively by, through or under Contributor or its Affiliates, and, except as set forth in the LLC Agreement, will not be subject to preemptive rights. The Acquiror Units comprising the Unit Purchase Price will be issued and granted in compliance in all material respects with (i) applicable securities Laws and other applicable Law (assuming the accuracy of the representations and warranties of the Contributor Parties set forth in Section  4.20 ) and (ii) all requirements set forth in applicable contracts. At Closing, the Class B Common Stock to be issued to Contributor will be duly authorized, validly issued, fully paid and non-assessable and such Class B Common Stock will not be subject to preemptive rights. Such Class B Common Stock will be issued and granted in compliance in all material respects with (i) applicable securities Laws and other applicable Law (assuming the accuracy of the representations and warranties of the Contributor Parties set forth in Section  4.20 ) and (ii) all requirements set forth in applicable contracts. As of the Closing, Acquiror Parent will have sufficient shares of authorized and unissued Class A Common Stock to issue the shares issuable on exchange of the Acquiror Units comprising the Unit Purchase Price.

5.14 Capitalization .

(a) As of February 6, 2017, the authorized capital of Acquiror Parent consisted solely of (i) 600,000,000 shares of Class A Common Stock, of which 205,030,033 shares of Class A Common Stock were issued and 204,890,617 shares of Class A Common Stock were outstanding (ii) 125,000,000 shares of Class B Common Stock, of which 28,008,573 were issued and outstanding, and (iii) 50,000,000 shares of preferred stock, $0.01 par value per share, of which no shares were issued and outstanding.

(b) All of the issued and outstanding shares of Common Stock are duly authorized and validly issued in accordance with the Organizational Documents of Acquiror Parent, are fully paid and non-assessable, and were not issued in violation of any preemptive rights, rights of first refusal, or other similar rights of any Person.

(c) There are no preemptive rights or, except as disclosed in the SEC Documents, other outstanding rights, options, warrants, conversion rights, stock appreciation rights, redemption rights, repurchase rights, agreements, arrangements, calls, subscription agreements, commitments or rights of any kind that obligate Acquiror Parent to issue or sell any equity interests of Acquiror Parent or any securities or obligations convertible or exchangeable into or exercisable for, or giving any Person a right to subscribe for or acquire, any equity interests in Acquiror Parent, and, except as disclosed in the SEC Documents, no securities or obligations evidencing such rights are authorized, issued or outstanding.

 

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(d) Acquiror Parent does not have any outstanding bonds, debentures, notes, or other obligations the holders of which have the right to vote (or convertible into or exercisable for securities having the right to vote) with the holders of equity interests in Acquiror Parent on any matter pursuant to such outstanding bonds, debentures, notes or other obligations.

(e) As of February 6, 2017, there were 232,899,190 issued and outstanding Acquiror Units. All of the issued and outstanding Acquiror Units have been duly authorized and validly issued in accordance with the Organizational Documents of Acquiror, are fully paid and non-assessable (except to the extent nonassessability may be affected by Section 18-607 of the Delaware LLC Act), and were not issued in violation of any preemptive rights, rights of first refusal, or other similar rights of any Person. The Acquiror Units owned by Acquiror Parent are owned by Acquiror Parent free and clear of all Encumbrances, other than those arising under Acquiror Parent’s financing documents, restrictions on transfer under federal and state securities Laws and as provided in the LLC Agreement.

5.15 SEC Documents, Financial Statements, No Liabilities .

(a) Acquiror Parent has timely filed or furnished with the Securities and Exchange Commission (the “ Commission ”) all reports, schedules, forms, statements, and other documents (including exhibits and other information incorporated therein) required to be filed or furnished by it since January 1, 2015 under the Securities Act or the Exchange Act (all such documents, collectively, the “ SEC Documents ”). The SEC Documents, including any audited or unaudited financial statements and any notes thereto or schedules included therein (the “ Financial Statements ”), at the time filed or furnished (except to the extent corrected by a subsequently filed or furnished SEC Document filed or furnished prior to the Execution Date) (i) did not contain any untrue statement of a material fact or omit to state a material fact required to be stated therein or necessary in order to make the statements therein (in the light of the circumstances under which they were made) not misleading, (ii) complied in all material respects with the applicable requirements of the Exchange Act and the Securities Act, as applicable, (iii) complied as to form in all material respects with applicable accounting requirements and with the published rules and regulations of the Commission with respect thereto, (iv) in the case of the Financial Statements, were prepared in accordance with GAAP applied on a consistent basis during the periods involved (except as may be indicated in the notes thereto or the omission of notes to the extent permitted by Regulation S-K or, in the case of unaudited statements, as permitted by Form 10-Q of the Commission) and subject, in the case of interim financial statements, to normal year-end adjustments, and (v) in the case of the Financial Statements, fairly present in all material respects the consolidated financial condition, results of operations, and cash flows of Acquiror Parent as of the dates and for the periods indicated therein.

(b) There are no liabilities of or with respect to the Acquiror Group that would be required by GAAP to be reserved, reflected, or otherwise disclosed on a consolidated balance sheet of Acquiror Parent other than (A) liabilities reserved, reflected, or otherwise disclosed in the consolidated balance sheet of Acquiror Parent as of September 30, 2016 (including the notes thereto) included in the Financial Statements, (B) liabilities incurred in the ordinary course of business consistent with past practice since September 30, 2016, (C) fees and expenses incurred in connection with the Transactions contemplated by this Agreement and the other Transaction Agreements or (D) liabilities that would not reasonably be expected to have an Acquiror Material Adverse Effect.

 

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5.16 Internal Controls; Listing Exchange .

(a) Acquiror Parent has established and maintains disclosure controls and procedures (as such term is defined in Rule 13a-15 under the Exchange Act) as required by Rule 13a-15 under the Exchange Act, such disclosure controls and procedures are reasonably designed to ensure that material information required to be disclosed by Acquiror Parent in the reports it files or submits to the Commission under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the rules and forms of the Commission, and that such material information is accumulated and communicated to Acquiror Parent’s management as appropriate to allow timely decisions regarding required disclosure.

(b) Since September 30, 2016, (A) Acquiror Parent has not been advised by its independent auditors of any significant deficiency or material weakness in the design or operation of internal controls that could adversely affect Acquiror Parent’s internal controls, (B) Acquiror Parent has no knowledge of any fraud, whether or not material, that involves management or other employees who have a significant role in Acquiror Parent’s internal controls, and (C) there have been no changes in internal controls or, to Acquiror Parent’s knowledge, in other factors that could reasonably be expected to materially affect internal controls, including any corrective actions with regard to any significant deficiency or material weakness.

(c) The Class A Common Stock is listed on the New York Stock Exchange (the “ NYSE ”), and Acquiror Parent has not received any notice of delisting from the NYSE. No judgment, order, ruling, decree, injunction, or award of any securities commission or similar securities regulatory authority or any other Governmental Authority, or of the NYSE, preventing or suspending trading in any securities of Acquiror Parent has been issued, and no proceedings for such purpose are, to Acquiror Parent’s knowledge, pending, contemplated or threatened. Acquiror Parent has taken no action that is designed to terminate the registration of the Class A Common Stock under the Exchange Act.

5.17 Compliance with Law . Except as to specific matters disclosed in the SEC Documents filed or furnished on or after January 1, 2016 and prior to the Execution Date (excluding any disclosures included in any “risk factor” section of such SEC Documents or any other disclosures in such SEC Documents to the extent they are predictive or forward looking and general in nature) or as would not, individually or in the aggregate, reasonably be expected to have an Acquiror Material Adverse Effect, (a) each Acquiror Party is, and during the past two years has been, in compliance in all material respects with all applicable Laws, (b) no Acquiror Party has received written notice of any violation in any respect of any applicable Law, and (c) no Acquiror Party has received written notice that it is under investigation by any Governmental Authority for potential non-compliance in any material respect with any Law. No Acquiror Party is subject to any material outstanding judgment, order or decree of any Governmental Authority.

5.18 Absence of Certain Changes . Since September 30, 2016, except as disclosed in the SEC Documents filed with the Commission prior to the Execution Date (excluding any disclosures included in any “risk factor” section of such SEC Documents or any other disclosures in such SEC Documents to the extent they are predictive or forward looking and general in nature), there has not occurred any Acquiror Material Adverse Effect or any event, occurrence, change, discovery or development of a state of circumstances or facts which would, individually or in the aggregate, reasonably be expected to result in an Acquiror Material Adverse Effect.

 

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5.19 Form S-3 . As of the Execution Date, Acquiror Parent is eligible to register the resale of the Class A Common Stock issuable upon exchange of the Acquiror Units comprising the Unit Purchase Price and the Class B Common Stock for resale by Contributor under Form S-3 promulgated under the Securities Act.

5.20 No Stockholder Approval . The Transactions contemplated hereby, taken together with any transactions consummated by Acquiror Parent as permitted by Article 6 , do not require any vote of the stockholders of Acquiror Parent under applicable Law, the rules and regulations of the NYSE (or other national securities exchange on which the Class A Common Stock is then listed) or the Organizational Documents of Acquiror Parent.

5.21 Taxes . Acquiror is treated as partnership for U.S. federal income tax purposes pursuant to Treas. Reg. § 301.7701-3.

5.22 Limitations . As used in this Agreement, “to the knowledge of Acquiror Parties”, “to Acquiror Parties’ knowledge”, or phrases of similar import means to the actual knowledge (after reasonable inquiry of the managers of each Acquiror Party with direct supervisory responsibility for the matters in question) of Matthew Gallagher, President and Chief Operating Officer, Michael W. Hinson, Senior Vice President—Corporate Development, and Paul Treadwell, Senior Vice President—Operations.

ARTICLE 6

COVENANTS OF THE PARTIES

6.1 Access . Subject to the limitations expressly set forth in this Agreement, the Contributor Parties shall, and shall cause the Company Group Members to, provide Acquiror and its representatives access to the Assets and access to and the right to copy, at Acquiror’s sole expense, the books and records of the Company Group in possession or control of any of the Contributor Group Members or Company Group Members for the purpose of conducting a confirmatory review of the Assets and the Company Group, but only to the extent (a) that Contributor Parties and Company Group Members may do so without violating applicable Laws and (b) the Contributor Parties have authority to grant such access without breaching any obligation of confidentiality binding on the Contributor Parties or any of their Affiliates. The Contributor Parties shall use reasonable efforts (including the assertion of any rights of any Contributor Group Member or any Company Group Member to information to which any such Contributor Group Member or any such Company Group Member is entitled pursuant to an applicable joint operating agreement or other Contract) to obtain permission for Acquiror to gain access to Properties operated by third Persons and the records and files of such third Persons to inspect the condition of such Properties, records, and files. Such access by Acquiror shall be limited to the Company Group’s normal business hours (or the periods of time agreed to by any third Person operator of a property, as applicable), and Acquiror’s investigation shall be conducted in a manner that minimizes interference with the operation of the business of Contributor and any applicable third Person operator. Without limitation of Acquiror’s rights pursuant to Section 3.5 , subject to the agreement and consent of any applicable third Person operator, Acquiror shall be entitled to conduct an environmental assessment, and may conduct visual inspections, record reviews, and interviews relating to the Assets of the Company Group operated by third Persons, including their condition and compliance with Environmental Laws.

 

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6.2 Press Releases . Neither the Contributor Parties nor the Acquiror Parties, nor any Affiliate thereof, shall make any press release or public disclosure regarding the existence of this Agreement, the contents hereof, or the transactions contemplated hereby without the prior written consent of Acquiror Parties (in the case of announcements by Contributor or its Affiliates) or Contributor (in the case of announcements by Acquiror Parties or their Affiliates), which consent, in each case, may be withheld for any reason or no reason; provided , however , the foregoing shall not restrict disclosures by Acquiror Parties or Contributor (i) to the extent that such disclosures are required by applicable securities or other Laws or the applicable rules of any stock exchange having jurisdiction over the disclosing Party or its Affiliates, (ii) to Governmental Authorities and third Persons holding Preferential Purchase Rights, rights of consent or other rights that may be applicable to the transactions contemplated by this Agreement, as reasonably necessary to provide notices, seek waivers, amendments or terminations of such rights, or seek such consents, (iii) to such Party’s investors and members, including each Parties’ Affiliates’ investors and limited partners, and to prospective investors or other Persons as part of fundraising or marketing activities undertaken by such Parties’ Affiliates provided such disclosures are made to Persons subject to an obligation of confidentiality with respect to such information or (iv) as may be necessary for, or permitted pursuant to, the exercise of the rights and fulfillment of the obligations of a Party under this Agreement. Contributor and Acquiror Parties shall each be liable for the compliance of its respective Affiliates with the terms of this Section 6.2 . The Parties agree that neither Acquiror Parties nor Contributor will have an adequate remedy at law if any of the foregoing Persons violate (or threaten to violate) any of the terms of this Section 6.2 . In such event, Acquiror Parties or Contributor, as applicable, shall have the right, in addition to any other it may have, to obtain injunctive relief to restrain any breach or threatened breach of the terms of this Section 6.2 without the posting of any bond.

6.3 Operation of Business . Until the Closing, each Company Group Member shall, and the Contributor Parties shall cause each Company Group Member to, operate its business and the Assets in the ordinary course, and, without limiting the generality of the foregoing and except as otherwise expressly contemplated by this Agreement or except as otherwise consented to in writing by Acquiror, the Contributor Parties and the Company Group Members shall, and the Contributor Parties shall cause the Company Group Members to, except as contemplated by Schedule 6.13 or as required by applicable Law, and except as set forth on Schedule 6.3 :

(a) not offer, issue, deliver, grant or sell, or authorize or propose to offer, issue, deliver, grant or sell, any Interests in any Company Group Member or any securities convertible into, or any rights, warrants or options to acquire, any such Interests, other than issuances by a wholly-owned Subsidiary of an Acquired Entity of such Subsidiary’s Interests to an Acquired Entity or any other wholly-owned Subsidiary of an Acquired Entity;

(b) not make any investment in or acquire Interests or other securities of, or make any capital contribution to, any Person other than a wholly-owned Subsidiary of an Acquired Entity;

 

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(c) not amend the Organizational Documents of any Company Group Member;

(d) not approve any operations on the Assets anticipated to cost the owner of the Assets (i) more than One Hundred Thousand Dollars ($100,000) per activity or series of related activities net to the Company Group’s interest (excepting, in each case, emergency operations required under presently existing contractual obligations and operations necessary to avoid material monetary penalty or forfeiture or nonconsent penalty under any provision of any applicable Contract or order of any Governmental Authority, all of which will be deemed to be approved, provided Contributor promptly notifies Acquiror of any emergency operation or operation to avoid monetary penalty or forfeiture excepted herein);

(e) except as expressly provided in Schedule 6.13 , not transfer, sell, hypothecate, encumber, or otherwise dispose of any of the Assets, except for (i) sales and dispositions of Hydrocarbons or equipment and materials made in the ordinary course of business which, in the case of equipment and materials, are replaced with equipment and materials of comparable or better value and utility in connection with the maintenance, repair, and operation of the Assets and (ii) other sales and dispositions of the Assets (other than Properties) individually not exceeding One Hundred Thousand Dollars ($100,000);

(f) produce Hydrocarbons from the Properties consistent with past practices, subject to the terms of the applicable Leases and Contracts, applicable Laws, and requirements of Governmental Authorities and interruptions resulting from force majeure, mechanical breakdown, and planned maintenance;

(g) not commit any of the Properties to any pooling agreement, unit agreement or amend any existing pooling agreement or unit agreement which is binding on the Properties;

(h) except with respect to agreements entered into in connection with activities contemplated by Schedule 6.13 , not (i) take any action to terminate, materially amend, or extend any Material Contract or (ii) enter into any agreement that, if in existence at the Execution Date would be a Material Contract; other than the execution or extension of a Contract for the sale, exchange, or marketing of oil, gas and/or other Hydrocarbons terminable without penalty on sixty (60) days or shorter notice;

(i) maintain insurance coverage on the Company Group and the Assets in the amounts and of the types presently in force and not make any election to be excluded from any coverage provided by an operator for the joint account pursuant to a joint operating agreement;

(j) maintain in full force and effect all Leases to the extent that such Leases are capable of producing in paying quantities at Hydrocarbon prices in effect as of the date that the Company Group or any third Person proposes to relinquish or release any such Leases or allow any such Leases to terminate (except for the termination of such Lease by its own terms);

(k) not grant or create any Preferential Purchase Right, right of first negotiation, option, or transfer restriction or similar right, obligation, or requirement, with respect to the Assets or the Company Group Interests, except in connection with the renewal or extension of Leases after the Effective Date if granting such right or requirement is a condition of such renewal or extension;

 

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(l) not incur any Indebtedness or take or fail to take any action that would cause a lien or encumbrance to arise or exist on the Assets or the Company Group Interests or otherwise allow a lien to attach to or encumber the Assets or the Company Group Interests;

(m) maintain all material governmental permits and approvals affecting the Company Group and the Assets;

(n) use commercially reasonable efforts to maintain and preserve intact the current organization, business and franchises of the Company Group and to preserve the rights, franchises, goodwill and relationships with their service providers, customers, lenders, suppliers, regulators and others having business relationships with the Company Group;

(o) not waive, release, assign, settle or compromise any claim, action or proceeding relating to the Company Group or the Assets;

(p) unless prohibited under Section 6.3(d) , not (i) elect not to participate in any operation or activity proposed with respect to the Properties, (ii) fail to timely make any election as to whether to participate in any operation or activity proposed with respect to the Properties or (iii) fail to make any payments due with respect to operations or activities proposed with respect to the Properties in which any Company Group Member has elected, or does elect, to participate, in each case, which could result in any of the Company Group’s interest in such Properties becoming subject to a penalty or forfeiture (including by deemed non-participation in an operation or activity proposed with respect to the Properties under an applicable operating agreement) as a result of such action or inaction of the types noted in subparts (i), (ii) or (iii) of this Section 6.3(p) ;

(q) not file any amended Tax Return, revoke or change any Tax election, change a Tax accounting period, enter into any closing agreement with respect to Taxes, settle any Tax claim or assessment, surrender any right to claim a refund of Taxes, or consent to any extension or waiver of the limitation period applicable to any Tax claim or assessment, in each case that would be reasonably likely to have the effect of materially increasing the Tax liability of the Company Group for any period after the Effective Date;

(r) not, except as required by the terms of any Contributor Benefit Plan as in effect on the date hereof, or involving increases, changes or other actions in the ordinary course of business, or have a substantially similar impact on employees who are not Available Employees, (A) grant, increase or accelerate the vesting or payment of, or announce or promise to grant, increase or accelerate the vesting or payment of, any wages, salaries, bonuses, incentives, severance pay, other compensation, pension or other benefits payable or potentially available to any Available Employee, including any increase or change pursuant to any Contributor Benefit Plan; provided , however , that nothing in this Section 6.3(r) shall restrict the payment of any bonuses or other incentive payments accrued for periods prior to the Closing Date; or (B) establish, adopt or amend (or promise to take any such action(s)) any Contributor Benefit Plan or any benefits potentially available thereunder applicable to any Available

 

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Employee (other than any amendments with respect to the separation of any Contributor Benefit Plan participants who are not Available Employees, and any related assets and Liabilities); provided , however that Contributor may, in its sole discretion, assign the sponsorship of any Contributor Benefit Plan or any other employee benefit or compensation plan, program or arrangement to any Affiliate of Contributor or to any other entity so long as such Affiliate or other entity is not a Company Group Member;

(s) not act in any manner with respect to the Assets other than in the normal, usual and customary manner, consistent with past practice (including paying or causing to be paid all associated costs and expenses, and meant to preserve intact the business and Assets and associated goodwill);

(t) not take any action that would or would reasonably be expected to prevent or materially delay the Closing and the consummation of the Transactions; and

(u) not agree or commit to do any of the foregoing.

Requests for approval of any action restricted by this Section 6.3 shall be delivered to the following individual, who shall have full authority to grant or deny such requests for approval on behalf of Acquiror:

Parsley Energy, LLC

303 Colorado Street

Suite 3000

Attention: Michael W. Hinson, Senior Vice

President – Corporate Development

Telephone: 737-704-2337

Email: mhinson@parsleyenergy.com

Acquiror’s approval of any action restricted by this Section 6.3 shall not be unreasonably withheld or delayed and shall be considered granted in full within five (5) Business Days of Contributor’s notice to Acquiror in accordance with this Section 6.3 requesting such consent, unless Acquiror notifies Contributor to the contrary during that period. Notwithstanding the foregoing provisions of this Section 6.3 , in the event of an emergency, Contributor may take such action as reasonably necessary and shall notify Acquiror of such action promptly thereafter. Acquiror acknowledges that the Company Group may own undivided interests in certain of the Assets, and Acquiror agrees that the acts or omissions of third Persons (including any applicable operator) who are not affiliated with Contributor shall not constitute a violation of the provisions of this Section 6.3 , nor shall any action required by a vote of Working Interest owners constitute such a violation so long as the applicable Company Group Member (and any applicable Affiliate) has voted its interests in a manner consistent with the provisions of this Section 6.3 . Notwithstanding anything to the contrary in this Section 6.3 , the Company Group may incur Indebtedness in the form of guarantees under the Contributor RBL prior to Closing, provided such Indebtedness is repaid in full at the Closing and any liens relating thereto are released.

 

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6.4 Indemnity Regarding Access . Acquiror’s access to the Assets and its (and its Affiliates’ and representatives’) examinations and inspections, pursuant to this Agreement or otherwise, shall be at Acquiror’s sole risk, cost, and expense, and Acquiror WAIVES AND RELEASES ALL CLAIMS AGAINST CONTRIBUTOR, ITS AFFILIATES, AND ITS AND THEIR RESPECTIVE PARTNERS, MEMBERS, OFFICERS, DIRECTORS, EMPLOYEES, ATTORNEYS, CONTRACTORS, AGENTS, OR OTHER REPRESENTATIVES, ARISING IN ANY WAY THEREFROM, OR IN ANY WAY CONNECTED THEREWITH, EXCEPT TO THE EXTENT ARISING FROM, OR RELATING TO, THE GROSS NEGLIGENCE OR WILLFUL MISCONDUCT OF ANY SUCH PERSON . Acquiror agrees to indemnify, defend and hold harmless Contributor and its Affiliates, the other owners of interests in the Properties, and all such Persons’ directors, officers, employees, agents, and representatives from and against any and all claims, liabilities, losses, costs, and expenses (including court costs and reasonable attorneys’ fees), including claims, liabilities, losses, costs, and expenses attributable to personal injury, death, or property damage, directly arising out of access to the Assets prior to the Closing by Acquiror, its Affiliates, or its or their respective directors, officers, employees, agents or representatives, EVEN IF CAUSED IN WHOLE OR IN PART BY THE NEGLIGENCE (WHETHER SOLE, JOINT OR CONCURRENT), STRICT LIABILITY OR OTHER LEGAL FAULT OF ANY INDEMNIFIED PERSON, EXCEPT TO THE EXTENT ARISING FROM, OR RELATING TO THE GROSS NEGLIGENCE OR WILLFUL MISCONDUCT OF ANY SUCH PERSON .

6.5 Hedges . Contributor Group shall take such actions as are necessary to cause all Hedging Transactions included in the Hedging Portfolio and outstanding at Closing to be transferred by novation from the Contributor Group Member party thereto to Parsley Energy, L.P. effective as of the Closing Date, pursuant to an agreement substantially in the form of the Novation Agreement published by the International Swaps and Derivatives Association, Inc. in 2002. Without the prior written consent of the Acquiror, (a) Contributor Group shall not take any action to early terminate, enter into any offsetting transaction, or otherwise unwind any Hedging Transaction included in the Hedging Portfolio or (b) enter into any additional Hedging Transactions or amend or otherwise modify the terms of any existing Hedging Transaction included in the Hedging Portfolio.

6.6 Enforcement of Third Party Provisions . To the extent pertaining to the Company Group, the Company Group Interests or the Assets and the period of time from and after the Effective Date, the Contributor Parties shall, at Acquiror Parties’ request, use reasonable efforts to cause the Company Group to enforce, for the benefit of Acquiror Parties, at Acquiror Parties’ cost and expense, all of Company Group’s rights against third Persons under any warranties, guarantees, or indemnities given by such third Persons.

6.7 Governmental Reviews .

(a) The Contributor Parties and the Acquiror Parties shall each in a timely manner (i) make (or cause their applicable Affiliates to make) all required filings, and prepare applications to, and conduct negotiations with, obtain consents, approvals or actions of, and give all notices to each Governmental Authority or any other Person as to which such filings, applications, negotiations, consents, approvals, actions or notices are necessary or appropriate in the consummation of the transactions contemplated hereby, and (ii) provide such information as the other may reasonably request in order to make such filings, prepare such applications,

 

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conduct such negotiations, obtain such consents approvals or actions, and give such notices. Each Party shall cooperate with and use all reasonable efforts to assist the other with respect to such filings, applications and negotiations. If a Party or any of its Affiliates intends to participate in any meeting or discussion with any Governmental Authority with respect to such filings, applications, or negotiations, or the transactions contemplated by this Agreement, it shall give the other Party reasonable prior notice of, and an opportunity to participate in, such meeting or discussion. Acquiror shall bear one-half and Contributor shall bear one-half of the cost of all filing or application fees payable to any Governmental Authority with respect to the transactions contemplated by this Agreement, regardless of whether Acquiror, Contributor, or any Affiliate of any of them is required to make the payment. Each Party shall provide prompt notice to the other Party when any such filings, application, negotiation, consent, approval, action or notice referred to above in this Section 6.7(a) is obtained, taken, made or given, as applicable, and will advise such other Party of any communications (and, unless precluded by Law, provide copies of any such written communications) with any Governmental Authority or other Person relating therewith.

(b) Without limiting the generality of Section 6.7(a) , as soon as practicable following the date of this Agreement and in any event within fifteen (15) Business Days after the date hereof, the Parties shall make such filings as may be required by the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, and the rules and regulations promulgated thereunder (the “ HSR Act ”) with respect to the transactions contemplated by this Agreement, which filings shall include a request for early termination of any applicable waiting period. Thereafter, the Parties shall file as promptly as practicable all reports or other documents required or requested by the U.S. Federal Trade Commission or the U.S. Department of Justice pursuant to the HSR Act or otherwise, including requests for additional information concerning such transactions, so that the waiting period specified in the HSR Act will expire or be terminated as soon as reasonably possible after the date of this Agreement. Each Party shall cause its counsel to furnish each of the other Parties such necessary information and reasonable assistance as such other Parties may reasonably request in connection with the Parties’ preparation of necessary filings or submissions under the provisions of the HSR Act.

6.8 No Shop . Until the earlier of the occurrence of Closing or the termination of this Agreement pursuant to Article 10 :

(a) The Contributor Parties and all other of the members of the Contributor Group and their respective Affiliates shall immediately cease and cause to be terminated any discussions or negotiations with any Persons with respect to any Third Party Acquisition or any proposal reasonably likely to lead to a Third Party Acquisition. From the date of this Agreement until the Closing, the Contributor Parties shall not, and shall not authorize or permit any of its Affiliates or any of their respective officers, directors, employees, representatives or agents to, and shall not resolve or propose to, directly or indirectly, (i) encourage, solicit, participate in or initiate discussions, negotiations, inquiries, proposals or offers (including any proposal or offer to their shareholders) with or from or provide any non-public information to any Person or group of Persons concerning any Third Party Acquisition or any inquiry, proposal or offer which may lead to a Third Party Acquisition or (ii) waive, terminate, modify or fail to enforce any provision of any contractual “standstill” or similar obligation of any Person.

 

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(b) Neither Contributor nor any other member of the Contributor Group shall enter into any agreement, letter of intent, memorandum of understanding, agreement in principle, acquisition agreement, merger agreement, option agreement, joint venture agreement, partnership agreement or other agreement constituting or directly related to, or which is reasonably likely to lead to, a Third Party Acquisition or any proposal for a Third Party Acquisition.

(c) For the purposes of this Agreement, “ Third Party Acquisition ” shall mean the occurrence of any acquisition, directly or indirectly, in one or a series of related transactions, whether by sale, merger or otherwise, all or any part of the Company Group Interests or all or any part of the Assets (except, in the case of Assets, as expressly permitted by Section 6.3 ).

6.9 Audits and Filings .

(a) From and after the date of this Agreement, the Contributor Parties shall, and shall use their reasonable efforts to cause their Affiliates and their and their respective officers, directors, managers, employees, agents and representatives to, cooperate with the Acquiror Parties, their Affiliates and their respective agents and representatives in connection with compliance with Acquiror Parties’ and their Affiliates’ Tax, financial, or other reporting requirements and audits, including (i) any filings with any Governmental Authority and (ii) any filings that may be required by the Commission, under securities Laws applicable to the Acquiror Parties and their Affiliates, including the filing by the Acquiror Parties with the Commission of one or more registration statements to register any securities of the Acquiror Parties under the Securities Act of 1933 (the “ Securities Act ”) or of any report required to be filed by the Acquiror Parties under the Exchange Act (together with the Securities Act and the rules and regulations promulgated under such acts, the “ Securities Laws ”) (any such filings described in clause (ii) , the “ Filings ”). Further, from and after the date of this Agreement, the Contributor Parties shall, and shall use their reasonable efforts to cause their Affiliates to, make available to the Acquiror Parties and their Affiliates and their agents and representatives any and all books, records, information and documents that are attributable to the Company Group or the Assets in the Contributor Parties’ or their Affiliates’ possession or control reasonably required by the Acquiror Parties, their Affiliates and their agents and representatives, in order for the Acquiror Parties or their Affiliates to prepare, if required to comply with the requirements of the Securities Laws in connection with such Filings, financial statements relating to the Company Group meeting the requirements of Regulation S-X under the Securities Act.

(b) Without limiting the generality of Section 6.9(a) , from and after the date of this Agreement, the Contributor Parties shall, and shall use their reasonable efforts to cause their Affiliates to, cooperate with the independent auditors chosen by the Acquiror Parties (“ Acquiror’s Auditor ”) in connection with any audit by Acquiror’s Auditor of any financial statements of the Company Group that the Acquiror Parties or any of their Affiliates require to comply with the requirements of the Securities Laws. Such cooperation will include (i) reasonable access to the Contributor Group’s and the Company Group’s officers, managers, employees, agents and representatives who were responsible for preparing or maintaining the financial records and work papers and other supporting documents used in the preparation of such financial statements as may be required by Acquiror’s Auditor to perform an audit or conduct a review in accordance with generally accepted auditing standards or to otherwise verify

 

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such financial statements, (ii) delivery of one or more customary representation letters from the Contributor Group or the Company Group to Acquiror’s Auditor that are reasonably requested by the Acquiror Parties to allow such auditors to complete an audit (or review of any financial statements) and to issue an opinion with respect to an audit of those financial statements required pursuant to this Section 6.9(b), (iii) using reasonable efforts to obtain the consent of the independent auditor(s) of the Company Group that conducted any audit of such financial statements to be named as an expert in any Filing or offering memorandum for any equity or debt financing of the Acquiror Parties, and (iv) using reasonable efforts to cause the independent auditor(s) of the Company Group that conducted any audit of such financial statements to provide customary “comfort letters” to any underwriter or purchaser in connection with any equity or debt financing of the Acquiror Parties. The Acquiror Parties will reimburse the Contributor Parties, within ten (10) Business Days after demand in writing therefor, for any out-of-pocket costs incurred by the Contributor Parties or their Affiliates in complying with the provisions of this Section 6.9 . Notwithstanding the foregoing, nothing herein shall expand the Contributor Parties’ representations, warranties, covenants, or agreements set forth in this Agreement or give the Acquiror Parties, their Affiliates, or any third Person any rights to which it is not entitled hereunder.

(c) Without limiting Sections 6.9(a) and 6.9(b) , the Contributor Parties shall provide Acquiror Parent with (i) audited consolidated financial statements of the Company Group as of and for the year ended December 31, 2016 and (ii) to the extent required to comply with applicable Securities Laws, unaudited consolidated financial statements of the Company Group as of March 31, 2017 and for the three months ended March 31, 2016 and 2017, in each case, as soon as reasonably practicable after the Closing Date (and in any event within seventy (70) days after the Closing Date) and prepared on the same basis as the Contributor Financial Statements.

6.10 Conduct of Acquiror Group . Except as set forth on Schedule 6.10 or with the prior written consent of Contributor, from the Execution Date until the Closing, each Acquiror Party shall, and shall cause the other Acquiror Group Members to, conduct its business and operations in the ordinary course and, without limiting the generality of the foregoing, each Acquiror Party shall not:

(a) amend its Organizational Documents;

(b) repurchase or otherwise acquire any shares of its capital stock for less than fair market value (other than (i) the repurchase, redemption or other acquisition or retirement for value of any such capital stock held by any current or former director or employee of any Acquiror Group Member pursuant to any director or employee equity subscription agreement or plan, stock option agreement or similar agreement or plan or (ii) in connection with the exercise of stock options or stock appreciation rights by way of cashless exercise); or declare, set aside or pay any dividend or other distribution payable in cash, shares of its capital stock, property, rights or otherwise with respect to any shares of its capital stock;

 

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(c) adopt any plan or agreement of complete or partial liquidation, dissolution, restructuring, recapitalization, merger, consolidation or other reorganization or otherwise effect any transaction whereby by any Person or group acquires more than a majority of the outstanding equity interests of either of the Acquiror Parties;

(d) take any action that would or would reasonably be expected to prevent or materially delay the Closing and the consummation of the Transactions;

(e) take any action or fail to take any action that would reasonably be expected to cause Acquiror to be treated, for U.S. federal income Tax purposes, as a corporation; or

(f) agree or commit to do any of the foregoing.

6.11 Listing of Unit Purchase Price . At the Closing, Acquiror and Acquiror Parent shall issue the Unit Purchase Price and Class B Common Stock, respectively, issuable pursuant to this Agreement in accordance with all applicable securities Laws and the rules and policies of the NYSE. Without limiting the generality of the foregoing, Acquiror Parent shall complete all such filings with the NYSE and otherwise take all such actions as may be reasonably necessary for the Class A Common Stock to be issued upon the exchange of the Acquiror Units comprising the Unit Purchase Price to be accepted by the NYSE for issuance and approved for listing thereon from and after the time of Closing, subject to official notice of issuance. If Acquiror Parent applies to have its Class A Common Stock or other securities traded on any principal stock exchange or market other than the NYSE, it shall include in such application the Class A Common Stock to be issued upon the exchange of the Acquiror Units comprising the Unit Purchase Price and will take such other action as is necessary to cause such Class A Common Stock to be issued upon the exchange of the Acquiror Units comprising the Unit Purchase Price to be so listed.

6.12 [Reserved] .

6.13 New Properties . The Parties agree to the terms and provisions contained in Schedule 6.13 attached hereto.

6.14 Employees .

(a) No later than ten (10) Business Days following the date of this Agreement, Contributor shall provide to Acquiror a list of the Available Employees to whom Acquiror or an Affiliate of Acquiror (such entity that makes employment offers the “ Acquiror Employer ”) may make offers of employment. Any offer of employment by Acquiror Employer to any Available Employee shall be made no later than thirty (30) days prior to the Transition Services Termination Date and be for employment beginning on the Transition Services Termination Date and subject to satisfaction of Acquiror Employer’s regular pre-hiring drug, background and qualification screening requirements and shall be on terms and conditions determined by Acquiror Employer in its sole discretion that are consistent with the terms of this Section 6.14 . Contributor, Contributor Representative and their respective Affiliates shall provide Acquiror and its Affiliates, as applicable, with reasonable access to the Available Employees in order to evaluate and/or interview such Available Employees and facilitate such offers, and shall not take any action to discourage any Available Employee from accepting an offer of employment from Acquiror Employer that is consistent with this Section 6.14 . On or before the date that is fifteen

 

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(15) days prior to the Transition Services Termination Date, Acquiror shall provide Contributor Representative with written notice of which Available Employees have received the offers contemplated by this Section 6.14 and which have accepted such offers. Those Available Employees who accept such offers and become employees of Acquiror Employer are referred to as the “ Transferred Employees .” A Transferred Employee shall become an employee of Acquiror Employer as of the “Transfer Date,” which, for each Transferred Employee, shall be the Transition Services Termination Date, except with respect to any Available Employee to whom an employment offer is made and who is not Actively Employed as of the Transition Services Termination Date, in which case the Transfer Date shall be the date upon which such individual is able to and does commence active duty with Acquiror Employer following the Transition Services Termination Date. “Actively Employed” shall mean that the individual is an employee of Contributor Representative or its Affiliate or designee on the day immediately prior to the Transition Services Termination Date and on the Transition Services Termination Date such individual is not on a leave of absence. It is understood and agreed that any Transferred Employee who is not Actively Employed as of the Transition Services Termination Date shall not become an employee of Acquiror Employer or be eligible to participate in any employee benefit plan of Acquiror Employer at any time prior to his or her Transfer Date.

(b) For a period of at least twelve (12) months following the Transition Services Termination Date or such shorter period as a Transferred Employee is employed with Acquiror Employer, Acquiror Employer shall ensure that such Transferred Employee is provided with (i) a base salary or base wage rate, as applicable, and bonus opportunities (on a pro rata basis for the portion of the current year such Transferred Employee is employed by Contributor, Contributor Representative or any of their respective Affiliates or designees that employ such Transferred Employee prior to the Transition Services Termination Date) no less favorable than those set forth on the schedule provided to Acquiror by Contributor no later than ten (10) Business Days following the date hereof, and (ii) such other compensation and employee benefits, as applicable, and incentive and bonus opportunities (on a pro rata basis for the portion of the current year such Transferred Employee is employed by Acquiror Employer) that are substantially comparable in the aggregate to those provided to similarly situated employees of Acquiror Employer.

(c) No later than each Transferred Employee’s Transfer Date, Contributor Representative or its Affiliate or designee will provide to Acquiror such Transferred Employee’s recognized credited service (identifying the purpose of such recognized credited service with respect to each applicable plan) under the applicable Contributor Benefit Plans as of the day immediately prior to such Transfer Date. Acquiror Employer shall provide with respect to each Transferred Employee full credit for eligibility, vesting (but not vesting under any equity-based award) and benefit accrual purposes (but not benefit accrual under any defined benefit pension plan) under each applicable Employee Benefit Plan of Acquiror and its Affiliates (collectively, the “ Acquiror Plans ”) for such Transferred Employee’s service with Contributor, Contributor Representative and their respective Affiliates and designees, if any, that employ such Transferred Employee prior to the Transfer Date, to the same extent recognized by such entities for corresponding purposes immediately prior to the Transfer Date; provided, that , to the extent permitted by applicable Laws, such service need not be recognized to the extent that such recognition would result in any duplication of benefits. Acquiror Employer shall use commercially reasonable efforts to provide or cause to be provided to each Transferred

 

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Employee and his or her eligible dependents credit for any co-payments and deductibles paid during the plan year prior to becoming eligible to participate in any Acquiror Plans under the analogous Contributor Benefit Plan (to the same extent that such credit was given under such Contributor Benefit Plan) in satisfying any applicable deductible or annual maximum out-of-pocket requirements under the applicable Acquiror Plan for such year. Acquiror shall use commercially reasonable efforts to cause each Acquiror Plan that provides welfare benefits and with respect to which a Transferred Employee is eligible to participate to waive any pre-existing condition restrictions applicable to such Transferred Employee and his or her eligible dependents and to provide eligibility for coverage to such individuals immediately upon the date such individual loses coverage under a corresponding Contributor Benefit Plan.

(d) If a Transferred Employee’s employment with Acquiror Employer is terminated during the twelve (12)-month period following the Closing Date pursuant to an Involuntary Termination (as defined below), then the Acquiror Employer shall provide severance pay to such Transferred Employee in an amount equal to the sum of (i) four (4) months’ of such Transferred Employee’s base salary or base wage rate (assuming 40-hour workweeks), and (ii) one-third of such Transferred Employee’s target level annual bonus opportunity for the calendar year in which the termination of such Transferred Employee’s employment occurs (or, if no such annual bonus opportunity exists, one-third of the amount of the annual bonus, if any, paid to such Transferred Employee for the immediately preceding calendar year), paid in a lump sum cash payment no later than sixty (60) days following the date of the termination of such Transferred Employee’s employment, provided that such Transferred Employee executes, and does not revoke within any revocation period provided, a release agreement in a form provided by Acquiror Employer releasing all claims against Contributor, Contributor Representative and their respective Affiliates, Acquiror Employer and specified related entities and other Persons and providing other terms and conditions as deemed appropriate by Acquiror Employer, and such release agreement becomes effective prior to the sixtieth (60 th ) day following the date of the termination of such Transferred Employee’s employment. For purposes of this Section 6.14(d) , “ Involuntary Termination ” means, with respect to a Transferred Employee, any termination of his or her employment with Acquiror Employer that does not result from a resignation by such Transferred Employee. Notwithstanding the foregoing, the term “Involuntary Termination” shall not include a termination due to such Transferred Employee’s (A) misconduct or material failure to perform employment-related duties, (B) indictment for any felony or a misdemeanor involving alleged moral turpitude, or (C) embezzlement or other misappropriation of funds or assets.

(e) No later than each Transferred Employee’s Transfer Date, Contributor Representative will provide to Acquiror the Transferred Employee’s current vacation time, sick time and other time-off balances under the applicable Contributor Benefit Plans as of the day immediately prior to such Transfer Date. Acquiror Employer shall credit each Transferred Employee with the amount of accrued but unused vacation time, sick time and other time-off benefits as such Transferred Employee had accrued with Contributor, Contributor Representative and any of their respective Affiliates and designees that employ such Transferred Employee prior to such Transferred Employee’s Transfer Date as of the Transfer Date.

 

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(f) On or before the Transfer Date of each Transferred Employee, Contributor Representative shall, or shall cause its Affiliates or designee to, take any necessary action to fully vest as of such date the Transferred Employee’s account balances and other benefits under all Contributor Benefit Plans that are employee pension benefit plans (as such term is defined in Section 3(2) of ERISA, determined without regard to Section 4(b) of ERISA).

(g) Contributor and Contributor Representative shall remain liable for, or cause one of their Affiliates or designees to remain liable for, all covered claims for health, accident, sickness, life and disability benefits that are deemed incurred while a Transferred Employee or his or her eligible dependents are covered under a Contributor Benefit Plan providing such benefits, and Acquiror or its Affiliate (including Acquiror Employer) shall be liable for all such covered claims by such Transferred Employee or his or her eligible dependents that are deemed incurred while such Transferred Employee or his or her eligible dependents are covered under an Acquiror Plan providing such benefits. For purposes of this paragraph, (A) a claim for health benefits (including claims for medical, prescription drug and dental expenses) will be deemed to have been incurred on the date on which the actual medical service, treatment or material was rendered to or received by the Transferred Employee or eligible dependent claiming such benefit and (B) in the case of any claim for benefits other than those designated in the preceding clause (A) (such as a claim for life insurance or disability benefits), a claim will be deemed to have been incurred upon the occurrence of the event giving rise to such claim. Claims for workers’ compensation benefits for a Transferred Employee arising out of occurrences prior to such Transferred Employee’s Transfer Date shall be the responsibility of Contributor, Contributor Representative or any of their Affiliates or designees that employ such Transferred Employee prior to such Transferred Employee’s Transfer Date. Claims for workers’ compensation benefits for a Transferred Employee arising out of occurrences on or after such Transferred Employee’s Transfer Date shall be the responsibility of Acquiror or its Affiliate (including Acquiror Employer).

(h) Contributor Representative shall, or shall cause one of its Affiliates or designees to, provide COBRA continuation coverage (within the meaning of section 4980B of the Code and the Treasury Regulations thereunder) to all individuals who are M & A qualified beneficiaries (within the meaning assigned to such term under Q&A-4 of Treasury Regulation section 54.4980B-9) with respect to the Transactions for the duration of the period to which such individuals are entitled to such coverage. Contributor Representative shall take any and all necessary actions to ensure that Acquiror and its Affiliates are not required to provide such continuation coverage to any such individual at any time.

(i) Acquiror shall be solely responsible for, and shall indemnify and hold harmless Contributor, Contributor Representative and their respective Affiliates with respect to, any and all losses, liability and expenses (including Taxes, penalties, judgments, fines, amounts paid or to be paid in settlement, costs of investigation and preparations, and fees, expenses, and disbursements of attorneys) arising out of or in connection with the selection process and decisions for selection of Available Employees for offers of employment as contemplated by Section 6.14(a) , and the employment of the Transferred Employees by Acquiror or its Affiliates on and following each Transferred Employee’s Transfer Date.

(j) Nothing in this Agreement shall constitute an amendment to, or be construed as amending, any Employee Benefit Plan sponsored, maintained or contributed to by Acquiror, Contributor, Contributor Representative, or any of their respective Affiliates. The provisions of this Section 6.14 are for the sole benefit of the Parties and nothing herein,

 

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expressed or implied, is intended or will be construed to confer upon or give to any Person (including, for the avoidance of doubt, any Entity Employee or other current or former employee (or spouse or dependent thereof) of Contributor, Contributor Representative or any of their respective Affiliates or designees), other than the Parties and their respective permitted successors and assigns, any legal or equitable or other rights or remedies (including with respect to the matters provided for in this Section 6.14 ) under or by reason of any provision of this Agreement. Nothing in this Agreement shall give any Transferred Employee or any other Person any right to continued employment or service, nor shall this Agreement restrict the right of Acquiror or any of its Affiliates to terminate the employment or service of any employee or service provider after the Closing.

(k) Other than as contemplated by this Section 6.14 , for the period beginning on the Transition Services Termination Date and ending on the date that is one year after the Transition Services Termination Date: (i) Contributor, Contributor Representative and their Affiliates will not solicit or induce for employment any Transferred Employee; and (ii) neither Acquiror nor its Affiliates will solicit or induce for employment any Entity Employee who is not a Transferred Employee. Notwithstanding the foregoing, nothing in this Section 6.14(k) shall prevent a Party or its Affiliate from making general solicitations of employment not targeted at a particular Entity Employee or group of Entity Employees or hiring any individual who responds to such a solicitation.

(l) None of the Acquiror Parties shall have any obligations under the WARN Act with respect to any of the Entity Employees who do not become Transferred Employees. Contributor Representative or its Affiliate shall bear any and all obligations and liability under the WARN Act owed to all Entity Employees who do not become Transferred Employees resulting, directly or indirectly, from any of the transactions contemplated in this Agreement.

6.15 Termination of Affiliate Agreements . On or before the Closing Date, except as set forth on Schedule 6.15 , the Contributor Parties shall cause all Affiliate Agreements to be terminated without any liability or obligation on the part of the Company Group from and after the Closing.

6.16 Further Assurances . After Closing, Contributor and Acquiror Parties each agree to take such further actions and to execute, acknowledge, and deliver all such further documents as are reasonably requested by the other for carrying out the purposes of this Agreement or of any document delivered pursuant to this Agreement.

6.17 Credit Agreement Consent . Acquiror shall obtain, prior to the End Date, the consent of the necessary lenders under the Credit Agreement to permit (i) the acquisition by Acquiror of the Company Group Interests and (ii) any other action required to consummate the transactions contemplated by this Agreement (the “ Credit Agreement Consent ”). The Parties acknowledge that a breach or failure to perform the covenants set forth in this section shall, for the avoidance of doubt, be a material breach resulting in a failure of the conditions to Closing of the Contributor Parties, and the Contributor Parties shall be entitled to exercise their remedies set forth in Section 10.3(a) with respect thereto.

 

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6.18 Amendment of Acquiror LLC Agreement . Prior to the Closing, Acquiror shall amend and restate the LLC Agreement (as amended, the “ A&R LLC Agreement ”) to include the terms set forth on Exhibit G hereto. Subject to the foregoing, prior to the Closing, Acquiror shall not amend or otherwise modify the LLC Agreement (except with respect to changes to the LLC Agreement to reflect the transfer of Acquiror Units or the admission of new members) without the consent of Contributor (which consent shall not be unreasonably withheld).

6.19 Amendment of Existing Registration Rights Agreement . Prior to the Closing, Acquiror and Acquiror Parent shall amend (or amend and restate) the Amended and Restated Registration Rights Agreement, dated as of May 29, 2014 (the “ Existing Registration Rights Agreement ”), by and between Acquiror, Acquiror Parent and the other parties thereto (as amended, the “ A&R Registration Rights Agreement ”) to include the terms set forth on Exhibit H hereto. Subject to the foregoing, Acquiror and Acquiror Parent shall not amend or otherwise modify the Existing Registration Rights Agreement prior to the Closing without the consent of Contributor (which consent shall not be unreasonably withheld).

6.20 Execution of Closing Deliverables . At Closing the Contributor shall cause the Contributor Representative and the Service Provider (as defined in the Transition Services Agreement), as applicable, to execute and deliver all items called for to be executed and delivered by such Persons pursuant to, and in accordance with, Section 8.2 of this Agreement (including the Transition Services Agreement, the Defect Escrow Agreement and the Indemnity Holdback Escrow Agreement).

ARTICLE 7

CONDITIONS TO CLOSING

7.1 Conditions of Contributor Parties to Closing . The obligations of the Contributor Parties to consummate the transactions contemplated by this Agreement are subject, at the option of the Contributor Parties, to the satisfaction on or prior to Closing of each of the following conditions:

(a) (i) The Acquiror Party Fundamental Representations shall be true and correct in all respects as of the date of this Agreement and as of the Closing Date as though made on and as of the Closing Date; and (ii) the other representations and warranties of the Acquiror Parties set forth in Article 5 shall be true and correct in all material respects (and in all respects in the case of representations and warranties qualified by materiality or Acquiror Material Adverse Effect) as of the date of this Agreement and as of the Closing Date as though made on and as of the Closing Date (other than representations and warranties that refer to a specified date, which need only be true and accurate as of such specified date) except for inaccuracies which would not, individually or in the aggregate, cause or reasonably be expected to cause an Acquiror Material Adverse Effect;

(b) The Acquiror Parties shall have performed and observed, in all material respects (and in all respects in the case of any covenants and agreements qualified by materiality or Acquiror Material Adverse Effect), all covenants and agreements to be performed or observed by Acquiror Parties under this Agreement prior to or on the Closing Date;

 

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(c) On the Closing Date, no injunction, order or award restraining, enjoining or otherwise prohibiting the consummation of the transactions contemplated by this Agreement shall have been issued and remain in force, and no suit, action, or other proceeding (excluding any such matter initiated by a Contributor Party or any of its Affiliates) shall be pending before any Governmental Authority or body of competent jurisdiction (or threatened) seeking to enjoin or restrain or otherwise prohibit the consummation of the transactions contemplated by this Agreement;

(d) All material consents and approvals of any Governmental Authority (including any under the HSR Act) required for the transfer of the Company Group Interests from Contributor to Acquiror as contemplated under this Agreement, except consents and approvals of assignments by Governmental Authorities that are customarily obtained after closing, shall have been granted, or the necessary waiting period (including any under the HSR Act) shall have expired, or early termination of the waiting period shall have been granted;

(e) The aggregate Title Defect Amounts and Environmental Defect Amounts asserted by Acquiror in good faith pursuant to Section 3.6(a) and Section 3.6(c) , respectively, shall be less than twenty percent (20%) of the Unadjusted Purchase Price;

(f) The Class A Common Stock issuable upon exchange of the Acquiror Units comprising the Unit Purchase Price and the Class B Common Stock pursuant to the LLC Agreement shall have been approved for listing on NYSE, subject only to official notice of issuance thereof;

(g) Acquiror Parties shall have delivered or be ready, willing and able to deliver all of the deliverables Acquiror Parties are required to deliver pursuant to Section 8.3 ;

(h) Acquiror Parties shall have delivered evidence, to the reasonable satisfaction of the Contributor, that the Credit Agreement Consent shall have been obtained;

(i) Acquiror shall have entered into the A&R LLC Agreement, which shall include all of the terms set forth on Exhibit G ; and

(j) Acquiror shall have entered into the A&R Registration Rights Agreement, which shall include all of the terms set forth on Exhibit H .

7.2 Conditions of Acquiror Parties to Closing . The obligations of Acquiror Parties to consummate the transactions contemplated by this Agreement are subject, at the option of Acquiror Parties, to the satisfaction on or prior to Closing of each of the following conditions:

(a) (i) The Contributor Party Fundamental Representations and the representation set forth in clause (a)(iii) of Section 4.14 shall be true and correct in all respects as of the date of this Agreement and as of the Closing Date as though made on and as of the Closing Date; and (ii) the other representations and warranties of the Contributor Parties set forth in Article 4 shall be true and correct in all material respects (and in all respects, in the case of representations and warranties qualified by materiality or Company Group Material Adverse Effect) as of the date of this Agreement and as of the Closing Date as though made on and as of the Closing Date (other than representations and warranties that refer to a specified date, which need only be true and correct on and as of such specified date) except for inaccuracies which would not, individually or in the aggregate, cause a Company Group Material Adverse Effect;

 

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(b) The Contributor Parties shall have performed and observed, in all material respects (and in all respects, in the case of any covenants and agreements qualified by materiality or Company Group Material Adverse Effect), all covenants and agreements to be performed or observed by them under this Agreement prior to or on the Closing Date;

(c) On the Closing Date, no injunction, order or award restraining, enjoining, or otherwise prohibiting the consummation of the transactions contemplated by this Agreement shall have been issued and remain in force, and no suit, action, or other proceeding (excluding any such matter initiated by any Acquiror Party or any of its Affiliates) shall be pending before any Governmental Authority or body of competent jurisdiction (or threatened) seeking to enjoin or restrain or otherwise prohibit the consummation of the transactions contemplated by this Agreement;

(d) All material consents and approvals of any Governmental Authority (including any under the HSR Act) required for the transfer of the Company Group Interests from Contributor to Acquiror as contemplated under this Agreement, except consents and approvals of assignments by Governmental Authorities that are customarily obtained after closing, shall have been granted or the necessary waiting period (including any under the HSR Act) shall have expired, or early termination of the waiting period shall have been granted;

(e) The aggregate Title Defect Amounts and Environmental Defect Amounts asserted by Acquiror in good faith pursuant to Section 3.6(a) and Section 3.6(c) , respectively, shall be less than twenty percent (20%) of the Unadjusted Purchase Price; and

(f) The Contributor Parties shall have delivered or be ready, willing and able to deliver all of the deliverables the Contributor Parties are required to deliver pursuant to Section 8.2 .

ARTICLE 8

CLOSING

8.1 Time and Place of Closing . The consummation of the contribution of the Company Group Interests contemplated by this Agreement (the “ Closing ”) shall, unless otherwise agreed to in writing by Acquiror and Contributor, take place at the offices of Acquiror, located at 303 Colorado Street, Suite 3000, Austin, Texas 78701, at 10:00 a.m., local time, on April 20, 2017 (the “ Target Closing Date ”), or if all conditions in Article 7 to be satisfied prior to Closing have not yet been satisfied or waived, as soon thereafter as such conditions have been satisfied or waived, subject to the provisions of Article 10 . The date on which the Closing occurs is referred to herein as the “ Closing Date .”

8.2 Obligations of the Contributor Parties at Closing . At the Closing, upon the terms and subject to the conditions of this Agreement, and subject to the simultaneous performance by Acquiror Parties of their obligations pursuant to Section 8.3 , the Contributor Parties shall deliver or cause to be delivered, among other things, the following:

 

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(a) to Acquiror Parties, counterparts of the Assignment Agreement, duly executed by Contributor;

(b) to Acquiror Parties, a certificate of non-foreign status of Contributor (or its regarded owner for U.S. federal income Tax purposes, if Contributor is an entity disregarded from its owner for U.S. federal income Tax purposes) meeting the requirements of Treasury Regulation Section 1.1445-2(b)(2);

(c) to Acquiror Parties, a certificate duly executed by an authorized officer of Contributor, dated as of the Closing, certifying on behalf of Contributor that the conditions set forth in Sections 7.2(a) and 7.2(b) have been fulfilled;

(d) to Acquiror Parties, a certificate duly executed by the secretary or any assistant secretary of each of the Contributor Parties, dated as of the Closing, (i) attaching and certifying on behalf of each Contributor Party complete and correct copies of the resolutions or unanimous consent of the board of directors, managers, members, partners, or other equivalent governing body of such Contributor Party authorizing the execution, delivery, and performance by such Contributor Party of this Agreement and the transactions contemplated hereby, and (ii) certifying on behalf of such Contributor Party the incumbency of each officer of such Contributor Party executing this Agreement or any document delivered in connection with the Closing;

(e) to Acquiror Parties, where notices of approval, consent, or waiver are received by the Contributor Parties pursuant to a filing or application under Section 6.7 , copies of those notices of approval;

(f) to Acquiror Parties, releases and terminations of any mortgages, deeds of trust, assignments of production, financing statements, fixture filings, and other Encumbrances and interests burdening the Company Group Interests or the Assets (including those related to guarantees by the Company Group under the Contributor RBL, as well as evidence of release or termination of such guarantees);

(g) joint written instructions to the Escrow Agent that Closing has occurred and that the Deposit, together with any interest thereon, should be disbursed to Contributor;

(h) to Acquiror Parties, the Preliminary Settlement Statement, duly executed by Contributor;

(i) to Acquiror Parties, an executed counterpart of the Registration Rights and Lock-Up Agreement duly executed by Contributor (and Contributor’s Designees receiving a portion of the Unit Purchase Price);

(j) to Acquiror Parties, a counterpart of the Indemnity Holdback Escrow Agreement, duly executed by Contributor Representative;

(k) to Acquiror Parties, a counterpart of the Defect Escrow Agreement, duly executed by Contributor Representative;

 

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(l) to Acquiror Parties, a duly executed counterpart of a joinder to the A&R LLC Agreement;

(m) to Acquiror Parties, a Transition Services Agreement in the form attached hereto as Exhibit I , duly executed by the Service Provider; and

(n) all other instruments, documents, and other items reasonably necessary to effectuate the terms of this Agreement, as may be reasonably requested by Acquiror Parties.

8.3 Obligations of Acquiror Parties at Closing . At the Closing, upon the terms and subject to the conditions of this Agreement, and subject to the simultaneous performance by the Contributor Parties of their obligations pursuant to Section 8.2 , Acquiror Parties shall deliver or cause to be delivered, among other things, the following:

(a) to Contributor, a wire transfer of the Cash Closing Payment in same-day funds;

(b) to Contributor (or Contributor’s Designees provided in writing to Acquiror prior to the Closing Date), (i) the number of Acquiror Units comprising the Unit Purchase Price, as adjusted by Section 2.2 , minus the Escrowed Defect Units and the Indemnity Holdback Units, and (ii) the corresponding number of shares of Class B Common Stock to be issued pursuant to Section 2.1(a) ;

(c) the number of Acquiror Units (and a corresponding number of shares of Class B Common Stock) comprising the Escrowed Defect Units and any amount of cash that comprises the Defect Escrow Cash Amount pursuant to Section 3.8(e) as applicable, to the Defect Escrow Account as provided in Section 3.8(e) ;

(d) the number of Acquiror Units (and a corresponding number of shares of Class B Common Stock) comprising the Indemnity Holdback Units and the Indemnity Holdback Cash to the Indemnity Holdback Escrow Account as provided in Section 8.5(a) ;

(e) to Contributor, counterparts of the Assignment Agreement, duly executed by Acquiror;

(f) to Contributor, a certificate by an authorized officer of each of Acquiror Parties, dated as of the Closing, certifying on behalf of such Acquiror Party that the conditions set forth in Sections 7.1(a) and 7.1(b) have been fulfilled;

(g) to Contributor, a certificate duly executed by the secretary or any assistant secretary of each Acquiror Party, dated as of the Closing, (i) attaching and certifying on behalf of such Acquiror Party complete and correct copies of the resolutions of the Board of Directors or other equivalent governing body of such Acquiror Party authorizing the execution, delivery, and performance by such Acquiror Party of this Agreement and the transactions contemplated hereby and (ii) certifying on behalf of such Acquiror Party the incumbency of each officer of such Acquiror Party executing this Agreement or any document delivered in connection with the Closing;

 

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(h) joint written instructions to the Escrow Agent that Closing has occurred and that the Deposit, together with any interest thereon, should be disbursed to Contributor;

(i) to Contributor, the Preliminary Settlement Statement, duly executed by Acquiror Parties;

(j) to Contributor, an executed counterpart of the Registration Rights and Lock-Up Agreement duly executed by Acquiror Parent;

(k) to Contributor, a duly executed counterpart of a joinder to the A&R LLC Agreement;

(l) to Contributor, a counterpart of the Indemnity Holdback Escrow Agreement, duly executed by the Acquiror Parties;

(m) to Contributor, a counterpart of the Defect Escrow Agreement, duly executed by the Acquiror;

(n) to Contributor, a counterpart of the Transition Services Agreement, duly executed by the Acquiror; and

(o) all other instruments, documents, and other items reasonably necessary to effectuate the terms of this Agreement, as may be reasonably requested by Contributor.

8.4 Adjusted Purchase Price and Post-Closing Purchase Price Adjustments .

(a) Not later than five (5) Business Days prior to the Closing Date, Contributor shall prepare and deliver to Acquiror, a draft preliminary settlement statement (the “ Preliminary Settlement Statement ”) setting forth (i) Contributor’s good faith estimate of the Adjusted Purchase Price for the Company Group Interests as of the Closing Date after giving effect to all adjustments set forth in Section 2.2 , (ii) the Persons, accounts, and amounts of disbursements that Contributor designates and nominates to receive the cash portion of the Adjusted Purchase Price less: (i) the amount of the Deposit; (ii) the Defect Escrow Cash Amount and (iii) the Indemnity Holdback Cash, which shall constitute the dollar amount to be payable by Acquiror to Contributor at Closing (the “ Cash Closing Payment ”), along with the wiring instructions for all such payments and disbursements and (iv) the Persons (who shall consist only of Persons who own, directly or indirectly through ownership of Interests in one or more other Persons, Interests in the Contributor Parties (“ Contributor’s Designees ”)) and whole number of Acquiror Units that Contributor designates and nominates to receive the Unit Purchase Price (each such Person, a “ Unit Recipient ”), as adjusted by Section 2.2 , less the Escrowed Defect Units and the Indemnity Holdback Units (the “ Stock Closing Payment ”). Contributor shall supply to Acquiror reasonable documentation in the possession of the Contributor Group or any of their Affiliates to support the items for which adjustments are proposed or made in the Preliminary Settlement Statement delivered by Contributor and a reasonably detailed explanation of any such adjustments and the reasons therefor. Within three (3) Business Days after receipt of Contributor’s draft Preliminary Settlement Statement, Acquiror will deliver to Contributor a written report containing all changes that Acquiror proposes to be made to the Preliminary Settlement Statement, if any, together with a brief explanation of any such changes. The

 

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Preliminary Settlement Statement, as agreed upon in writing by the Parties (subject to further adjustments under Section 8.4(b) , will be used to adjust the Unadjusted Purchase Price at Closing; provided that if the Parties cannot agree on all adjustments set forth in the Preliminary Settlement Statement prior to the Closing, then any adjustments as set forth in the Preliminary Settlement Statement as presented by Contributor will be used to adjust the Unadjusted Purchase Price at Closing.

(b) As soon as reasonably practicable after the Closing but not later than the one hundred and twentieth (120th) day following the Closing Date, Contributor shall prepare and deliver to Acquiror a draft statement setting forth the final calculation of the Adjusted Purchase Price and showing the calculation of each adjustment under Section 2.2 , based on the most recent actual figures for each adjustment; provided , however , that for purposes of making such final calculation, the adjustment amounts made pursuant to Sections 2.2(b)(vi) , 2.2(b)(vii) and 2.2(b)(viii) shall be assumed to be in the same amounts as the amounts used for such adjustments in calculating the Adjusted Purchase Price in the Preliminary Settlement Statement. Contributor shall include in such notice such reasonable documentation as is in the Contributor Group’s possession to support the final figures. As soon as reasonably practicable, but not later than the thirtieth (30th) day following receipt of such statement from Contributor, Acquiror shall deliver to Contributor a written report containing any changes that Acquiror proposes be made to such statement, and in order to be valid, any such written report by Acquiror shall specify in reasonable detail the dollar amount, nature and basis of any changes so asserted. Contributor may deliver a written report to Acquiror during this same period reflecting any changes that Contributor proposes to be made to such statement as a result of additional information received after the statement was prepared. If Acquiror does not deliver such report to Contributor on or before the end of such thirty (30) day period (or, if Contributor proposes any changes to such statement, thirty (30) days from the date Contributor delivers written notice thereof to Acquiror), Acquiror shall be deemed to have agreed with Contributor’s statement, and such statement shall become final and binding upon the Parties. The Parties shall undertake to agree on the final statement of the Adjusted Purchase Price no later than ninety (90) days after delivery of Contributor’s statement. In the event that the Parties cannot reach agreement within such period of time, any Party may refer the items of adjustment which are in dispute to the Houston, Texas office of PricewaterhouseCoopers LLP, or, if such Person is not able or willing to serve, a nationally recognized independent accounting firm or consulting firm mutually acceptable to both Acquiror and Contributor (the “ Accounting Arbitrator ”), for review and final determination by arbitration. If Acquiror and Contributor have not agreed upon a mutually acceptable alternate Person to serve as Accounting Arbitrator within ten (10) Business Days of receiving notice of PricewaterhouseCoopers LLP’s unavailability, Contributor shall, within ten (10) Business Days after the end of such initial ten (10) Business Day period, formally apply to the Houston, Texas office of the American Arbitration Association to choose the Accounting Arbitrator. The Accounting Arbitrator shall conduct the arbitration proceedings in Houston, Texas in accordance with the Commercial Arbitration Rules of the American Arbitration Association, to the extent such rules do not conflict with the terms of this Section 8.4(b) . The Accounting Arbitrator’s determination shall be made within forty-five (45) days after submission of the matters in dispute and shall be final and binding on all Parties, without right of appeal. In determining the proper amount of any adjustment to the Adjusted Purchase Price, the Accounting Arbitrator shall be bound by the terms of Article 2 and may not increase the Adjusted Purchase Price more than the increase proposed by Contributor nor decrease the Adjusted Purchase Price more than the

 

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decrease proposed by Acquiror, as applicable. The Accounting Arbitrator shall act as an expert for the limited purpose of determining the specific disputed aspects of adjustments submitted by any Party and may not award damages, interest or penalties to any Party with respect to any matter. Contributor and Acquiror shall each bear their own legal fees and other costs of presenting its case. Contributor shall bear one-half and Acquiror shall bear one-half of the costs and expenses of the Accounting Arbitrator.

(c) Any difference in the Adjusted Purchase Price as determined pursuant to Section 8.4(a) and the finally determined Adjusted Purchase Price as determined pursuant to Section 8.4(b) shall be paid in cash by the owing Party to the owed Party within five (5) Business Days after the earlier of (i) the expiration of Acquiror’s thirty (30) day review period (including any extensions provided for above) without delivery of any written report, (ii) the date on which the Parties agree in writing as to the final Adjusted Purchase Price, or (c) the date on which the Accounting Arbitrator finally determines the Adjusted Purchase Price.

(d) Acquiror shall assist Contributor in preparation of the final statement of the Adjusted Purchase Price under Section 8.4(b) by furnishing invoices, receipts, and providing reasonable access to personnel and such other assistance as may be requested by Contributor to facilitate such process post-Closing.

(e) All cash payments made or to be made under Section 8.4(c) to Contributor (or its designees) or Acquiror shall be made by electronic transfer of immediately available funds to Contributor (or its designees) or Acquiror, as applicable, or to such other bank and account as may be specified by Contributor or Acquiror in writing.

(f) Following the adjustments made under Section 8.4(b) , no further adjustments shall be made to the Adjusted Purchase Price but nothing in this Section 8.4(f) is a limitation on Schedule 6.13 .

8.5 Indemnity Holdback .

(a) On the Closing Date, Acquiror shall deposit into the Indemnity Holdback Escrow Account (i) 4,921,557 Acquiror Units (such Acquiror Units, together with any cash and non-cash dividends, securities and other property at any time received in exchange or respect of or otherwise in substitution of the such Indemnity Holdback Units or the shares of Class A Common Stock for which such Indemnity Holdback Units may be exchanged pursuant to the LLC Agreement, collectively, the “ Indemnity Holdback Units ”) and a corresponding number of shares of Class B Common Stock and (ii) One Hundred Seventy-Two Million Two Hundred Fifty-Four Thousand Five Hundred Eight Dollars ($172,254,508) in cash (the “ Indemnity Holdback Cash ”), for the purpose of securing the satisfaction and discharge of indemnity claims of the Acquiror Parties against the Contributor Parties under this Agreement. The Indemnity Holdback Units (and the corresponding number of shares of Class B Common Stock) to be deposited into the Indemnity Holdback Escrow Account will be issued in the name of the Unit Recipients, whether in book-entry or certificated form, with each Unit Recipient being issued such Unit Recipient’s Pro Rata Share of the Indemnity Holdback Units (and a corresponding number of shares of Class B Common Stock). For the avoidance of doubt, the Indemnity Holdback Units and Indemnity Holdback Cash represent a deduction from, and are not in

 

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addition to, the Adjusted Purchase Price paid by Acquiror to Contributor on the Closing Date. The Indemnity Holdback Escrow Account shall be governed by the provisions of this Section 8.5 and an escrow agreement that the Acquiror and Contributor Representative shall execute and deliver at Closing to the Escrow Agent and which shall be in customary form (which the Parties agree shall provide for the prompt disbursement from the escrow account to the registered holders of Indemnity Holdback Units any tax distributions made in respect of such Indemnity Holdback Units pursuant Section 6.2 of the A&R LLC Agreement) and contain terms and provisions consistent with this Section 8.5 (the “ Indemnity Holdback Escrow Agreement ”); provided, however, that if such Parties are unable to enter into any such Indemnity Holdback Escrow Agreement or otherwise deposit the Indemnity Holdback Cash and Indemnity Holdback Units into the Indemnity Holdback Escrow Account, then the Parties shall provide for and enter into appropriate alternative arrangements to give effect to the provisions of this Section 8.5 . The joint, written authorization of representatives of the Acquiror and the Contributor Representative pursuant to the Indemnity Holdback Escrow Agreement shall be required for the disbursement of any portion of the Indemnity Holdback Units or the Indemnity Holdback Cash. Each disbursement of Indemnity Holdback Units pursuant to this Section 8.5 and the Indemnity Holdback Escrow Agreement shall be accompanied by a disbursement of a corresponding number of shares of Class B Common Stock. Whenever any disbursement of Indemnity Holdback Units is made, such disbursement shall be comprised of Indemnity Holdback Units registered in the name of all Unit Recipients, with each Unit Recipient bearing or receiving, as applicable, its Pro Rata Share of such disbursement. Notwithstanding anything herein to the contrary, no fractional Acquiror Units or fractional shares of Common Stock shall be disbursed from the Indemnity Holdback Escrow Account, and, to the extent that any such fractional security would be required to be so disbursed but for this sentence, such fractional security shall be rounded up or down to the nearest whole number of the applicable securities.

(b) With respect to each claim for indemnification asserted by the Acquiror Parties against the Contributor Parties pursuant to Article 11 during the period from and after the Closing Date up to the date that is twenty-four (24) months following the Closing Date (the “ Holdback Period ”), upon final resolution or determination of such an indemnity claim by the Parties or in accordance with Section 12.5 , such amount as would satisfy such finally resolved or determined indemnity claim will be satisfied exclusively from the Indemnity Holdback Escrow Account and Acquiror and Contributor shall jointly instruct the Escrow Agent to disburse to Acquiror Indemnity Holdback Units and Indemnity Holdback Cash with a total value equal to the amount to be so disbursed (valuing such Indemnity Holdback Units at the Per Share Value, pro rata in the same proportions that the Indemnity Holdback Units (valuing such Indemnity Holdback Units at the Per Share Value) bear to the total value contained in the Indemnity Holdback Escrow Account at the time of such disbursement, with the number of Indemnity Holdback Units to be disbursed determined by valuing such Indemnity Holdback Units at the Per Share Value. For the avoidance of doubt, the sole and exclusive recourse of Acquiror Parties for any breach of any representation, warranty or covenant of the Contributor Parties pursuant to this Agreement or any other post-Closing liability of the Contributor Parties pursuant to this Agreement (including any indemnity obligation), other than any liability arising as a result of actual (and not constructive) fraud, is limited to disbursements that may be made from the Indemnity Holdback Escrow Account.

 

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(c) If, upon the resolution or determination of any such indemnity claim during the Holdback Period, Acquiror and Contributor fail to deliver a joint written instruction to the Escrow Agent in accordance with Section 8.5(b) , then the Escrow Agent shall, upon delivery by Acquiror or Contributor to the Escrow Agent of a written final, non-appealable court order from a court of competent jurisdiction, disburse to Acquiror Indemnity Holdback Units and Indemnity Holdback Cash with a value equal to the amounts set forth in such court order (valuing such Indemnity Holdback Units at the Per Share Value for such purpose), pro rata in the same proportions that the Indemnity Holdback Units (valuing such Indemnity Holdback Units at the Per Share Value) bear to the total value contained in the Indemnity Holdback Escrow Account at the time of such disbursement, with the number of Indemnity Holdback Units to be disbursed determined by valuing such Indemnity Holdback Units at the Per Share Value.

(d) Acquiror and Contributor shall jointly instruct the Escrow Agent to release to Contributor (i) on the first Business Day after the date that is twelve months following the Closing Date, any Indemnity Holdback Units then-remaining in the Indemnity Holdback Escrow Account and any Indemnity Holdback Cash then-remaining in the Indemnity Holdback Escrow Amount having a total value equal to the total value contained in the Indemnity Holdback Escrow Account at such time, less (A) an amount equal to 2.5% of the Unadjusted Purchase Price (valuing the Indemnity Holdback Units at the Per Share Value) and (B) Indemnity Holdback Units and Indemnity Holdback Cash having a total value equal to the aggregate amount of all outstanding claims for indemnification which the Acquiror Parties have provided to the Contributor Parties that have not been previously satisfied (valuing the Indemnity Holdback Units at the Per Share Value for such purposes) (which Indemnity Holdback Units and Indemnity Holdback Cash shall remain part of the Indemnity Holdback Escrow Account until final resolution of such outstanding indemnity claims (the “ Initial Release Disputed Claims ”), with such Indemnity Holdback Cash and Indemnity Holdback Units being disbursed pro rata based on the proportions that each bear to the total value contained in the Indemnity Holdback Escrow Account at such time (valuing the Indemnity Holdback Units at the Per Share Value) and (ii) on the first Business Day after the expiration of the Holdback Period, any Indemnity Holdback Units and Indemnity Holdback Cash then-remaining in the Indemnity Holdback Escrow Account, in each case except for any Indemnity Holdback Units and Indemnity Holdback Cash retained in the Indemnity Holdback Escrow Account at such time in respect of any Initial Release Disputed Claims and Indemnity Holdback Units and Indemnity Holdback Cash having a total value equal to the aggregate amount of all outstanding claims for indemnification made subsequent to the date that is 12 months following the date of this Agreement for which the Acquiror Parties have provided to the Contributor Parties that have not been previously satisfied (valuing the Indemnity Holdback Units at the Per Share Value for such purposes) (which Indemnity Holdback Units and Indemnity Holdback Cash shall remain part of the Indemnity Holdback Escrow Account until final resolution of such outstanding indemnity claims (the “ Final Release Disputed Claims ” and, together with the Initial Release Disputed Claims, the “ Disputed Claims ”). Upon final resolution or determination of any Disputed Claim by the Parties or in accordance with Section 12.5 , Acquiror and Contributor shall deliver to the Escrow Agent joint written instructions to disburse to the Acquiror Indemnity Holdback Units and Indemnity Holdback Cash having a value equal to the amount so finally determined to be owed to the Acquiror Parties (valuing such Indemnity Holdback Units at the Per Share Value), pro rata in the same proportions that the Indemnity Holdback Units (valuing such Indemnity Holdback Units at the Per Share Value) bear to the total value contained in the Indemnity

 

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Holdback Escrow Account at the time of such disbursement, with the number of Indemnity Holdback Units to be disbursed determined by valuing such Indemnity Holdback Units at the Per Share Value, and all other Indemnity Holdback Units and Indemnity Holdback Cash remaining in the Indemnity Holdback Escrow Account in respect of such Disputed Claim shall be disbursed to Contributor. If the Acquiror and Contributor fail to deliver a joint written instruction to the Escrow Agent in accordance with the foregoing sentence, then the Escrow Agent shall, upon delivery by Acquiror or Contributor to the Escrow Agent of a written final, non-appealable court order from a court of competent jurisdiction relating to such Disputed Claim disburse the Indemnity Holdback Units and Indemnity Holdback Cash in respect of such Disputed Claim as provided in the immediately preceding sentence.

8.6 Removal of Name . As promptly as practicable, but in any case within 60 days after the Closing Date, Acquiror Parties shall eliminate Contributor’s name, its logo and any variants thereof from the Assets and, except with respect to such grace period for eliminating existing usage, shall have no right to use any logos, trademarks or trade names belonging to Contributor or any of its Affiliates.

ARTICLE 9

TAX MATTERS

9.1 Straddle Period Tax Proration . For purposes of determining the allocations of Taxes imposed on the Company Group, or for which it is otherwise liable, for any Straddle Period that are attributable to the portion of such Straddle Period ending prior to the Effective Date: (A) Asset Taxes that are attributable to the severance, production or sale of Hydrocarbons shall be allocated to the portion of such Straddle Period in which the severance or production giving rise to such Asset Taxes occurred, (B) Taxes that are (i) Income Taxes, (ii) imposed in connection with any sale or other transfer or assignment of property (real or personal, tangible or intangible) or (iii) imposed on specific transactions, including payroll taxes, shall be allocated to the portion of such Straddle Period in which the transaction giving rise to such Taxes occurred, and (C) Asset Taxes that are ad valorem, property or other Asset Taxes imposed on a periodic basis pertaining to a Straddle Period shall be allocated between the portion of such Straddle Period ending prior to the Effective Date and the portion of such Straddle Period beginning on or after the Effective Date by prorating each such Asset Tax based on the number of days in the applicable Straddle Period that occur before the Effective Date, on the one hand, and the number of days in such Straddle Period that occur on or after the Effective Date, on the other hand; provided however, that exemptions, allowances or deductions that are calculated on an annual basis (including depreciation and amortization deductions) shall be allocated between the period ending prior to the Effective Date and the period beginning on or after the Effective Date in proportion to the number of days in each period. Regardless of which Party is responsible, Contributor shall handle payment to the appropriate Governmental Authority of all Taxes which are required to be paid prior to the Closing Date, and the Company Group shall handle payment to the appropriate Governmental Authority of all Taxes required to be paid on and after the Closing Date.

 

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9.2 Tax Returns . Contributor shall be responsible for filing with the applicable taxing authorities each Company Group Tax Return that is required to be filed on or before the Closing Date. With respect to any Tax Return for any taxable period (or portion thereof) beginning on or after the Effective Date, Contributor shall provide a copy of such Tax Return to the Acquiror no later than ten (10) days before the due date of such Tax Return for Acquiror’s comments and approval and shall not file such Tax Return without the Acquiror’s consent (which shall not be unreasonably withheld, conditioned or delayed); provided, however, that the preceding shall not apply to Tax Returns relating to sales, use, payroll, or other Taxes that are required to be filed contemporaneously with, or promptly after, the close of a Tax period, which shall be provided to Acquiror promptly after filing. Contributor shall timely file such Tax Return (after incorporating the comments from Acquiror) before the due date of such Tax Return. Acquiror shall be responsible for filing with the applicable taxing authorities each Company Group Tax Return that is required to be filed after the Closing Date.

9.3 Transfer Taxes . To the extent that any sales, purchase, transfer, stamp, documentary stamp, registration, use or similar taxes are payable by reason of the sale of the Company Group Interests under this Agreement (“ Transfer Taxes ”), such Transfer Taxes shall be borne and timely paid by Acquiror. Acquiror and Contributor shall reasonably cooperate in good faith to minimize, to the extent permissible under applicable Law, the amount of any such Transfer Taxes.

9.4 Tax Cooperation . The Parties shall cooperate fully, as and to the extent reasonably requested by the other Party, in connection with the filing of Tax Returns and any audit, litigation, or other proceeding with respect to Taxes imposed on or with respect to the Company Group. Such cooperation shall include the retention and (upon another Party’s request) the provision of records and information that are relevant to any such Tax Return or audit, litigation or other proceeding and making employees available on a mutually convenient basis to provide additional information and explanation of any material provided under this Agreement. Contributor and Acquiror agree to retain all books and records with respect to Tax matters pertinent to the Company Group relating to any taxable period beginning before the Closing Date until the expiration of the statute of limitations of the respective taxable periods and to abide by all record retention agreements entered into with any Governmental Authority.

9.5 754 Elections . Contributor shall, prior to the Closing, cause each Tax Partnership that is scheduled with respect to Section 4.3(j) to either (x) have in effect a valid election under Section 754 of the Code (or similar provisions of state, local or foreign Law) for any taxable year that includes the Closing Date or (y) obtain all necessary consents therefor.

9.6 1031 Like-Kind Exchange Cooperation . Contributor and Acquiror agree that either or both of Contributor and Acquiror may elect to treat the acquisition or sale of the Company Group Interests as an exchange of like-kind property under section 1031 of the Code (an “ Exchange ”). Each Party agrees to use reasonable efforts to cooperate with the other Parties in the completion of such an Exchange including an Exchange subject to the procedures outlined in Treasury Regulation section 1.1031(k)-1 and/or Internal Revenue Service Revenue Procedure 2000-37. Each of Contributor and Acquiror shall have the right at any time prior to Closing to assign its rights under this Agreement to a qualified intermediary (as that term is defined in Treasury Regulation Section 1.1031(k)-1(g)(4)(v)) or an exchange accommodation titleholder (as that term is defined in Internal Revenue Service Revenue Procedure 2000-37) to effect an Exchange. In connection with any such Exchange, any exchange accommodation title holder shall have taken all steps necessary to own the Company Group Interests under applicable law.

 

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Each Party acknowledges and agrees that neither an assignment of a Party’s rights under this Agreement nor any other actions taken by a Party or any other person in connection with the Exchange shall release any Party from, or modify, any of their respective liabilities and obligations (including indemnity obligations to each other) under this Agreement, and no Party makes any representations as to any particular tax treatment that may be afforded to any other Party by reason of such assignment or any other actions taken in connection with the Exchange. Any Party electing to treat the acquisition or sale of the Company Group Interests as an Exchange shall be obligated to pay all additional costs incurred hereunder as a result of the Exchange, and in consideration for the cooperation of the other Parties, the Party electing Exchange treatment shall agree to pay all costs associated with the Exchange and to indemnify and hold each other Party, its affiliates, and their respective former, current and future partners, members, shareholders, owners, officers, directors, managers, employees, agents and representatives harmless from and against any and all liabilities and Taxes arising out of, based upon, attributable to or resulting from the Exchange or transactions or actions taken in connection with the Exchange that would not have been incurred by the other Parties but for the electing Party’s Exchange election.

9.7 Purchase Price Allocation . On or before sixty (60) days after the Closing Date, Acquiror shall deliver to Contributor a proposed allocation of the fair market value of the Company Group (determined based upon the Adjusted Purchase Price) among the Assets in accordance with Section 1060 of the Code and Treasury Regulations thereunder (and any similar provision of state, local or foreign Law, as applicable), which shall also be consistent with the Allocated Values (the “ Proposed Tax Allocation ”). Contributor shall have thirty (30) days following its receipt of the Proposed Tax Allocation to review such Proposed Tax Allocation and if Contributor does not provide Acquiror with a timely Allocation Objection Notice, the allocations set forth in the Proposed Tax Allocation shall be deemed agreed upon. If, however, Contributor objects to the Proposed Tax Allocation, it must provide written notice of any such objection within the foregoing thirty (30) day period (the “ Allocation Objection Notice ”). Subsequent to Acquiror’s receipt of the Allocation Objection Notice, the Parties shall cooperate in good faith to reach a mutually agreeable allocation. If the Parties do not reach a mutually agreeable allocation of such fair market value of the Company Group within thirty (30) days of Acquiror’s receipt of the Allocation Objection Notice, the Parties shall submit any disputes as to such allocation to the Accounting Arbitrator. The Parties shall instruct the Accounting Arbitrator to, within thirty (30) days of its engagement by the Parties, determine the appropriate allocation and to provide written notice of its determination to the Parties (such allocation mutually agreed to by the Parties, deemed agreed to by the Parties, or finally determined by the Accounting Arbitrator, as applicable, the “ Final Allocation ”). The Final Allocation schedule shall be updated to reflect any subsequent adjustments to the Adjusted Purchase Price. All fees and expenses charged by the Accounting Arbitrator pursuant to this Section 9.7 will be allocated between the Parties in inverse proportion as each shall prevail in respect of the dollar amount of disputed adjustments so submitted (as finally determined by the Accounting Arbitrator) (or, if such formula is inapplicable, such fees and expenses shall be borne by the Parties in an equitable manner, as determined by the Accounting Arbitrator). Acquiror and Contributor agree not to take any position or file any Tax Return inconsistent with the Final Allocation unless required by applicable Law or a “determination” within the meaning of Section 1313(a)(1) of the Code; provided , however , that nothing in this Agreement will prevent a Party from settling any proposed deficiency or adjustment by any Governmental Authority based upon or arising out of

 

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the Final Allocation, and neither Party will be required to litigate before any court any proposed deficiency or adjustment by any Governmental Authority challenging the final allocation, as applicable. Each Party shall promptly notify the others upon receipt of notice of any pending or threatened Tax audit or assessment challenging the Final Allocation.

9.8 Tax Treatment .

(a) The Contributor Parties intend to treat, for U.S. federal income and applicable state and local Tax purposes, the Contribution and Liquidations, taken together, as an “assets-over” partnership merger transaction under Treasury Regulation Sections 1.708-1(c)(1) and 1.708-1(c)(3)(i), whereby DEEP will be the terminating partnership and Acquiror will be the resulting partnership.

(b) The Contribution shall be treated for U.S. federal income Tax purposes as a contribution of the assets and properties of the Company Group Members to Acquiror in exchange for the Unit Purchase Price and the assumption of any liabilities that constitute “qualified liabilities” within the meaning of Treasury Regulation Section 1.707-5(a)(6) which is not treated as a transfer of consideration made pursuant to a sale of the assets to the Acquiror under Treasury Regulation Section 1.707-5(a)(5) in a transaction consistent with the requirements of Section 721(a) of the Code, to the extent applicable. To the maximum extent allowed pursuant to Treasury Regulation Section 1.707-4(d), any amounts treated as a transfer of cash or other consideration pursuant to Treasury Regulation Section 1.707-3(a)(1)) shall be treated as a reimbursement of preformation capital expenditures described in Treasury Regulation Section 1.707-4(d). The sum of (i) cash and other consideration not treated as reimbursement of preformation capital expenditures and (ii) the amount of consideration treated as sale proceeds in connection with the assumption of any liability by Acquiror under Treasury Regulation Section 1.707-5(a)(5) will be treated as proceeds of a disguised sale transaction described in Section 707(a)(2)(B) of the Code. The Parties agree to prepare and file all U.S. federal income Tax Returns in accordance with the foregoing and shall not take any position inconsistent therewith on any such Tax Return, or in the course of any audit, litigation or other proceeding with respect to U.S. federal income Taxes, except as otherwise required by applicable Laws, following a final determination by a court of competent jurisdiction or other final administrative decision by an applicable Governmental Authority.

ARTICLE 10

TERMINATION

10.1 Termination . This Agreement may be terminated at any time prior to Closing: (a) by the mutual prior written consent of the Contributor Parties and the Acquiror Parties, (b) by either the Contributor Parties or the Acquiror Parties if the Closing has not occurred on or before 5:00 pm local time in Houston, Texas on May 19, 2017 (the “ End Date ”) or (c) by the Contributor Parties, in the event that prior to 5:00 p.m. local time in Houston, Texas on the date two (2) Business Days after the Execution Date Purchaser fails to fund into escrow with the Escrow Agent pursuant to Section 2.1(b) the entirety of the Deposit; provided , however , that, no Party shall be entitled to terminate this Agreement under Section 10.1(b) if the Closing has failed to occur as a result of such Party’s breach of any representations or warranties set forth herein or such Party’s failure to perform or observe such Party’s covenants and agreements hereunder

 

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(including the failure to perform the obligations of such Party with respect to Closing the transactions contemplated hereunder if and when required) in each case in a manner that causes the conditions of the other Party in Article 7 not to be satisfied (a “ Material Breach ”); provided , however , that if the Closing has not occurred or this Agreement has not otherwise been terminated by the date that is 30 days following the End Date and the Acquiror Parties have not initiated any action for specific performance of the Contributor Parties’ obligations to consummate the Transactions (or at any time after such an action has been initiated, the Acquiror Parties fail to use reasonable best efforts to pursue such action), then, notwithstanding anything to the contrary in clause (b)  of this Section 10.1 , the Contributor Parties shall be entitled to terminate this Agreement by delivering written notice to the Acquiror Parties.

10.2 Effect of Termination . If this Agreement is terminated pursuant to Section 10.1 , this Agreement shall become void and of no further force or effect (except for the provisions of Section 1.2 , this Article 10 , Sections 4.8 , 5.11 , 6.2, 6.4 , and Article 12 (other than Section 12.17 , all of which shall continue in full force and effect).

10.3 Distribution of Deposit Upon Termination; Damages for Failure to Close .

(a) In the event that (i) all conditions precedent to the obligations of Acquiror Parties set forth in Section 7.2 have been satisfied or waived in writing by Acquiror Parties (except for those conditions that by their nature are to be satisfied at Closing, all of which the Contributor Parties stand ready, willing and able to satisfy) and (ii) the Contributor Parties are entitled to terminate this Agreement under Section 10.1(b) because the conditions precedent to the obligations of Contributor set forth in Section 7.1 are not satisfied as of the date set forth in Section 10.1(b) solely as a result of the breach or failure of Acquiror Parties’ representations, warranties, or covenants hereunder, including, if and when required, Acquiror Parties’ obligations to consummate the transactions contemplated hereunder at Closing, then Contributor shall be entitled to elect, in its sole discretion, to either (x) seek specific performance of this Agreement, or (y) to terminate this Agreement and receive the entirety of the Deposit, together with an amount in cash equal to an additional five percent (5%) of the Unadjusted Purchase Price, (the “ Liquidated Damages Payment ” and, together with the Deposit, the “ Liquidated Damages Amount ”) for the sole account and use of Contributor as liquidated damages and as its sole remedy hereunder. If Contributor terminates this Agreement pursuant to Section 10.1(c) , Acquiror shall promptly pay to Contributor an amount in cash equal to ten percent (10%) of the Unadjusted Purchase Price (a “ Deposit Damages Payment ”). Contributor and Acquiror acknowledge and agree that (A) Contributor’s actual damages upon the event of a termination described in this Section 10.3(a) are difficult to ascertain with any certainty, (B) the Liquidated Damages Amount (and the amount of the payment described in the immediately preceding sentence) is a fair and reasonable estimate by the Parties of such aggregate actual damages of Contributor, and (C) such liquidated damages do not constitute a penalty. Upon the occurrence of a termination by Contributor pursuant to this Section 10.3(a) , Contributor and Acquiror shall, as applicable, either (a) execute and deliver joint written instructions to the Escrow Agent to disburse the Deposit together with any income thereon to Contributor, and Acquiror shall pay to Contributor in cash the Liquidated Damages Payment by wire transfer of immediately available funds to a bank account or accounts to be designated in writing by Contributor or (b) pay to Contributor in cash the Deposit Damages Payment by wire transfer of immediately available funds to a bank account or accounts to be designated in writing by Contributor.

 

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(b) In the event that (i) all conditions precedent to the obligations of Contributor set forth in Section 7.1 have been satisfied or waived in writing by Contributor (except for those conditions that by their nature are to be satisfied at Closing, all of which Acquiror Parties stand ready, willing and able to satisfy) and (ii) Acquiror Parties are entitled to terminate this Agreement under Section 10.1(b) because the conditions precedent to the obligations of Acquiror Parties set forth in Section 7.2 are not satisfied as of the date set forth in Section 10.1(b) solely as a result of the breach or failure of Contributor’s representations, warranties, or covenants hereunder, including, if and when required, Contributor’s obligations to consummate the transactions contemplated hereunder at Closing, then Acquiror shall be entitled to elect, in its sole discretion, to either (A) seek specific performance of this Agreement, or (B) terminate this Agreement, in which event Acquiror shall be entitled to (x) receive the entirety of the Deposit for the sole account and use of Acquiror Parties and (y) seek Damages available to Acquiror at Law or in equity up to an amount equal to ten percent (10%) of the Unadjusted Purchase Price, and in the case of clause (B) , Contributor and Acquiror shall execute and deliver joint written instructions to the Escrow Agent to disburse the Deposit together with any income thereon to Acquiror.

(c) If this Agreement is terminated for any reason other than the reasons set forth in Section 10.3(a) or Section 10.3(b) , Acquiror shall be entitled to receive the Deposit, free of any claims by Contributor or any other Person with respect thereto. In such event, Contributor and Acquiror shall execute and deliver joint written instructions to the Escrow Agent to disburse the Deposit together with any income thereon to Acquiror.

ARTICLE 11

INDEMNIFICATION; LIMITATIONS

11.1 Indemnification .

(a) From and after Closing, Acquiror shall indemnify, defend, and hold harmless Contributor and its Affiliates and its and their respective officers, directors, managers, partners, employees, and agents (the “ Contributor Family ”) from and against all Damages incurred or suffered by Contributor Family caused by, arising out of, or resulting from:

(i) any Acquiror Parties’ breach of any of Acquiror Parties’ covenants or agreements contained in Article 6 ; or

(ii) any breach of any representation or warranty made by any Acquiror Party contained in Article 5 of this Agreement or in the certificate delivered at Closing pursuant to Section 8.3(f) ,

EVEN IF SUCH DAMAGES ARE CAUSED IN WHOLE OR IN PART BY THE NEGLIGENCE (WHETHER SOLE, JOINT OR CONCURRENT), STRICT LIABILITY OR OTHER LEGAL FAULT OF ANY INDEMNIFIED PERSON , INVITEE OR THIRD PERSON, AND WHETHER OR NOT CAUSED BY A PRE-EXISTING CONDITION, BUT EXCLUDING THE GROSS NEGLIGENCE OR WILLFUL MISCONDUCT OF ANY INDEMNIFIED PERSON , and further excepting in each case Damages against which the Contributor Parties would be required to indemnify the Acquiror Parties under

 

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Section 11.1(b) .

(b) From and after Closing, the Contributor Parties shall indemnify, defend, and hold harmless the Acquiror Parties and their Affiliates and their respective officers, directors, employees, and agents (“ Acquiror Family ”) from and against all Damages incurred or suffered by Acquiror Family:

(i) caused by or arising out of, or resulting from, the following:

(A) the Excluded Assets;

(B) any matters that are required to be borne by the Contributor Group under Section 2.2 ;

(C) any Contributor Taxes;

(D) any injury, death, or third Person property damage attributable to, or arising out of, the ownership or operation of the Assets prior to Closing;

(E) matters that are caused by, arise out of, or result from the off-site disposal of any Hazardous Materials that were either (i) generated or used on the Assets or (ii) disposed of by any Company Group Member or any of their Affiliates, in each case, to the extent that such disposal occurred prior to the Closing Date;

(F) any civil fines or penalties or criminal sanctions imposed on any Contributor Group Member or any Company Group Member or any of its or their Affiliates to the extent relating to any pre-Closing violation of Law by any such Person;

(G) Matters that are attributable to litigation existing as of the Closing Date set forth on Schedule 4.2 ;

(H) obligations and liabilities to any employees of any Contributor Group Member or any Company Group Member or any of their Affiliates, the employment or termination thereof, and the compensation and benefits inuring thereto, in each case, solely to the extent arising prior to the Closing; or

(I) any Contributor Group Member’s or any Company Group Member’s or any of their Affiliates’ responsibilities or liabilities under the Contributor Benefit Plans.

(ii) caused by, arising out of, or resulting from, any Contributor Party’s breach of any of such Contributor Party’s covenants or agreements contained in Article 6 ; or

(iii) caused by, arising out of, or resulting from, any breach of any representation or warranty made by the Contributor Parties contained in Article 4 of this Agreement, or in the certificates delivered at Closing pursuant to Section 8.2(c) ,

 

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EVEN IF SUCH DAMAGES ARE CAUSED IN WHOLE OR IN PART BY THE NEGLIGENCE (WHETHER SOLE, JOINT OR CONCURRENT), STRICT LIABILITY OR OTHER LEGAL FAULT OF ANY INDEMNIFIED PERSON, INVITEE, OR THIRD PERSON, AND WHETHER OR NOT CAUSED BY A PRE-EXISTING CONDITION, BUT EXCLUDING THE GROSS NEGLIGENCE OR WILLFUL MISCONDUCT OF ANY INDEMNIFIED PERSON, and further excepting in each case Damages against which Acquiror would be required to indemnify Contributor under Section 11.1(a) .

(c) Notwithstanding anything to the contrary contained in this Agreement, from and after Closing, the Contributor Parties’ and the Acquiror Parties’ sole and exclusive remedy against each other with respect to breaches of the representations, warranties, covenants, and agreements of the Parties contained in Article 4 , Article 5 , Article 6 (excluding Sections 6.2 and 6.9 , which shall be separately enforceable by the Parties pursuant to whatever rights and remedies are available to them outside of this Article 11 , but which, for the avoidance of doubt, shall be subject to the last sentence of Section 8.5(b) ), and the affirmations of such representations, warranties, covenants, and agreements contained in the certificates delivered by each Party at Closing pursuant to Sections 8.2(c) and 8.3(f) , as applicable, is set forth in this Section 11.1 .

(d) The Parties shall treat, for Tax purposes, any amounts paid pursuant to this Article 11 as an adjustment to the Adjusted Purchase Price, except as otherwise required under applicable Law.

11.2 Indemnification Actions . All claims for indemnification under Section 11.1 shall be asserted and resolved as follows:

(a) For purposes of this Article 11 , the term “ Indemnifying Person ” when used in connection with particular Damages shall mean the Person having an obligation to indemnify another Person or Persons with respect to such Damages pursuant to this Article 11 , and the term “ Indemnified Person ” when used in connection with particular Damages shall mean a Person having the right to be indemnified with respect to such Damages pursuant to this Article 11 (including, for the avoidance of doubt, those Persons identified in Section 11.2(h) ).

(b) To make a claim for indemnification under Section 11.1 , an Indemnified Person shall notify the Indemnifying Person of its claim, including the specific details of and specific basis under this Agreement for its claim (the “ Claim Notice ”). In the event that the claim for indemnification is based upon a claim by a third Person against the Indemnified Person (a “ Claim” ), the Indemnified Person shall provide its Claim Notice promptly after the Indemnified Person has actual knowledge of the Claim and shall enclose a complete copy of all papers (if any) served with respect to the Claim; provided that the failure of any Indemnified Person to give notice of a Claim as provided in this Section 11.2 shall not relieve the Indemnifying Person of its obligations under Section 11.1 , except to the extent such failure results in insufficient time being available to permit the Indemnifying Person to effectively defend against the Claim or otherwise prejudices the Indemnifying Person’s ability to defend against the Claim. In the event that the claim for indemnification is based upon an inaccuracy or breach of a representation, warranty, covenant, or agreement, the Claim Notice shall specify the representation, warranty, covenant or agreement that was inaccurate or breached and the reasonably specific details of, and specific basis for, such asserted inaccuracy or breach.

 

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(c) In the case of a claim for indemnification based upon a Claim, the Indemnifying Person shall have thirty (30) days from its receipt of the Claim Notice to notify the Indemnified Person whether it admits or denies its obligation to defend the Indemnified Person against such Claim under this Article 11 . If the Indemnifying Person does not notify the Indemnified Person within such thirty (30) day period regarding whether the Indemnifying Person admits or denies its obligation to defend the Indemnified Person, it shall be deemed to have denied its obligation to provide such indemnification hereunder. The Indemnified Person is authorized, prior to and during such thirty (30) day period, to file any motion, answer or other pleading that it shall deem necessary or appropriate to protect its interests or those of the Indemnifying Person and that is not prejudicial to the Indemnifying Person.

(d) If the Indemnifying Person admits its obligation, it shall have the right and obligation to diligently defend, at its sole cost and expense, the Claim. The Indemnifying Person shall have full control of such defense and proceedings, including any compromise or settlement thereof. If requested by the Indemnifying Person, the Indemnified Person agrees to cooperate in contesting any Claim which the Indemnifying Person elects to contest ( provided , however , that the Indemnified Person shall not be required to bring any counterclaim or cross-complaint against any Person). The Indemnified Person may participate in, but not control, any defense or settlement of any Claim controlled by the Indemnifying Person pursuant to this Section 11.2(d) . Notwithstanding the foregoing, the Indemnifying Person shall not have the right to defend any Claim relating to Taxes for which the Indemnifying Person does not have sole liability. Such Claims shall be defended jointly by the Indemnified Person and the Indemnifying Person. An Indemnifying Person shall not, without the written consent of the Indemnified Person, settle any Claim or consent to the entry of any judgment with respect thereto that (i) does not result in a final, non-appealable, resolution of the Indemnified Person’s liability with respect to the Claim (including, in the case of a settlement, an unconditional written release of the Indemnified Person from all further liability in respect of such Claim) or (ii) may materially and adversely affect the Indemnified Person (other than as a result of money damages covered by the indemnity).

(e) If the Indemnifying Person does not admit its obligation or admits its obligation but fails to diligently defend or settle the Claim, then the Indemnified Person shall have the right to defend against the Claim (at the sole cost and expense of the Indemnifying Person, if the Indemnified Person is entitled to indemnification hereunder), with counsel of the Indemnified Person’s choosing, subject to the right of the Indemnifying Person to admit its obligation to indemnify the Indemnified Person and assume the defense of the Claim at any time prior to settlement or final, non-appealable determination thereof. If the Indemnifying Person has not yet admitted its obligation to indemnify the Indemnified Person, the Indemnified Person shall send written notice to the Indemnifying Person of any proposed settlement and the Indemnifying Person shall have the option for ten (10) days following receipt of such notice to (i) admit in writing its obligation for indemnification with respect to such Claim and (ii) if its obligation is so admitted, assume the defense of the Claim, including the power to reject the proposed settlement. If the Indemnified Person settles any Claim over the objection of the Indemnifying Person after the Indemnifying Person has timely admitted its obligation for indemnification in writing and assumed the defense of the Claim, the Indemnified Person shall be deemed to have waived any right to indemnity therefor.

 

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(f) If a Party would be required to defend a Claim as provided in this Section 11.2 , which Claim is unliquidated in amount, but for the assertion that the other Party would not be entitled to indemnification for any liability, loss, cost, expense, claim, award, judgment, or other Damages incurred or suffered by such Party due solely to the limitations set forth in Section 11.3(c) with respect to the amount of such Claim, such Party shall nevertheless have the right and obligation to defend against such Claim as set forth in Section 11.2(d) , subject to the indemnification obligations of such Party set forth in this Article 11 ; provided , however , that if, upon final, non-appealable liquidation of the amount of such Claim, the Party defending such Claim pursuant to this Section 11.2(f) would not have had the obligation to defend such Claim under Section 11.3(c) due solely to the limitations set forth in Section 11.3(c) with respect to the amount of such Claim, the Party defending such Claim shall be entitled to reimbursement of all reasonable costs and expenses incurred with respect to the defense of such Claim.

(g) In the case of a claim for indemnification not based upon a Claim, the Indemnifying Person shall have thirty (30) days from its receipt of the Claim Notice to (i) cure the Damages complained of, (ii) admit its obligation to provide indemnification with respect to such Damages or (iii) dispute the claim for such Damages. If the Indemnifying Person does not notify the Indemnified Person within such thirty (30) day period that it has cured the Damages or that it disputes the claim for such Damages, the Indemnifying Person shall be conclusively deemed to have disputed the claim for indemnification hereunder.

(h) Any claim for indemnity under Section 11.1 by any Affiliate, director, officer, employee or agent must be brought and administered by the applicable Party to this Agreement. No Indemnified Person other than Contributor and Acquiror shall have any rights against either Contributor or Acquiror under the terms of Section 11.1 except as may be exercised on its behalf by Acquiror or Contributor, as applicable, pursuant to this Section 11.2(h) . Each of Contributor and Acquiror may elect to exercise or not exercise indemnification rights under this Section 11.2 on behalf of the other Indemnified Persons affiliated with it in its sole discretion and shall have no liability to any such other Indemnified Person for any action or inaction under this Section 11.2 .

11.3 Limitation on Actions .

(a) The Acquiror Party Fundamental Representations, Contributor Group Fundamental Representations, the Special Warranty of Title, the covenants of the Contributor Parties in this Agreement to be performed at or prior to Closing, and the corresponding representations, warranties, and affirmations given in the certificate delivered at Closing pursuant to Sections 8.2(c) and 8.3(f) , shall terminate upon the expiration of the Holdback Period. All other representations and warranties of the Contributor Parties in this Agreement, and the corresponding representations, warranties, and affirmations given in the certificates delivered at Closing pursuant to Sections 8.2(c) and 8.3(f) , shall terminate on the date that is twelve (12) months after the Closing Date. The representations and warranties of Acquiror Parties in Article 5 (excluding the Acquiror Party Fundamental Representations) and the covenants of the Acquiror Parties in this Agreement to be performed at or prior to Closing, and

 

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the corresponding representations, warranties, and affirmations given in the certificates delivered at Closing pursuant to Sections 8.2(c) and 8.3(f) , shall survive the Closing for a period of twelve (12) months. The covenants and agreements of the Parties to be performed after Closing shall survive Closing as reasonably necessary to perform the same, subject to Section 8.5 and the limitations set forth in this Section 11.3 . Representations, warranties, covenants, and agreements shall be of no further force and effect after the date of their expiration, provided that there shall be no termination of any bona fide claim asserted pursuant to this Agreement with respect to such a representation, warranty, covenant, or agreement prior to its expiration date.

(b) The indemnities in Sections 11.1(a)(i) , 11.1(a)(ii) , 11.1(b)(ii) and 11.1(b)(iii) shall terminate as of the termination date of each respective representation, warranty, covenant, or agreement that is subject to indemnification, except in each case as to matters for which a specific written claim for indemnity has been delivered to the Indemnifying Person on or before such termination date. The indemnities in Section 11.1(b)(i) shall terminate as of expiration of the Holdback Period.

(c) No Party shall have any liability for any indemnification under Section 11.1(a)(ii) or Section 11.1(b)(iii) , as applicable, for an individual matter until and unless the amount of the liability for Damages with respect to which such Party admits (or it is otherwise finally determined) that such Party has an obligation to indemnify the other Party pursuant to the terms of Section 11.1 exceeds Seventy-Five Thousand Dollars ($75,000) (the “ Individual Indemnity Threshold ”). Without limiting the foregoing, no Party shall have any liability for any indemnification under Section 11.1(a)(ii) or Section 11.1(b)(iii) , as applicable, until and unless the aggregate amount of the liability for all Damages (i) for which Claim Notices are delivered by the other Party, (ii) with respect to which such Party admits (or it is otherwise finally determined) that such Party has an obligation to indemnify the other Party pursuant to the terms of Article 11 , and (iii) which exceed the Individual Indemnity Threshold exceeds two percent (2.0%) of the Unadjusted Purchase Price, and then only to the extent such Damages exceed two percent (2.0%) of the Unadjusted Purchase Price; provided , however , that this Section 11.3(c) shall not limit indemnification for breaches of the Contributor Party Fundamental Representations, breaches of the Special Warranty of Title, breaches of the representations and warranties in Section 4.3 , and the Acquiror Party Fundamental Representations; and provided , further , that, for the purposes of this Article 11 , any representation, warranty, or covenant set forth in this Agreement which is qualified by materiality, Company Group Material Adverse Effect or Acquiror Material Adverse Effect shall be deemed not to be so qualified.

(d) Notwithstanding anything to the contrary contained elsewhere in this Agreement, other than in respect of any Damages resulting from actual fraud (and not on any theory of constructive fraud) by the Contributor Parties, the Contributor Parties shall not be required to indemnify Acquiror under this Article 11 for Damages other than through disbursement of the Indemnity Holdback Units and the Indemnity Holdback Cash pursuant to Section 8.5 .

(e) The amount of any Damages for which an Indemnified Person is entitled to indemnity under this Article 11 shall be reduced by the amount of insurance proceeds realized by the Indemnified Person or its Affiliates with respect to such Damages (net of any collection costs, and excluding the proceeds of any insurance policy issued or underwritten by the Indemnified Person or its Affiliates); provided , however , that no Party shall be required to seek recovery under any policy of insurance as a condition to indemnification hereunder.

 

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(f) As used in this Agreement, the term “ Damages ” means the amount of any actual liability, loss, cost, expense, claim, award, or judgment incurred or suffered by any Indemnified Person arising out of or resulting from the indemnified matter or any breach of this Agreement, whether attributable to personal injury or death, property damage, contract claims, torts, or otherwise, including reasonable fees and expenses of attorneys, consultants, accountants, or other agents and experts reasonably incident to matters indemnified against, and the costs of investigation and/or monitoring of such matters, and the costs of enforcement of the indemnity. Notwithstanding the foregoing, neither the Acquiror Parties nor the Contributor Parties shall be entitled to indemnification under this Article 11 for, and Damages shall not include, (i) consequential, special, or punitive damages suffered by the Party claiming indemnification (other than consequential, special, or punitive damages suffered by third Persons for which responsibility is allocated among the Parties), and (ii) any increase in liability, loss, cost, expense, claim, award or judgment to the extent such increase is caused by the actions or omissions of any Indemnified Person after the Closing Date.

(g) Notwithstanding anything to the contrary contained in this Agreement, a claim for indemnity may be made by a Party under this Article 11 in respect of any breach of any representation, warranty or covenant set forth in this Agreement despite the fact that such Party obtained knowledge prior to the execution and delivery of this Agreement or prior to the Closing of the breach of such representation, warranty or covenant. In furtherance of the foregoing, each of Acquiror Parties and Contributor Parties are entitled to rely upon, and shall be deemed to have relied upon, all representations, warranties and covenants of the other Party set forth in this Agreement which are made in favor of Acquiror Parties or Contributor, as applicable, and the rights of the members of Acquiror Family and Contributor Family who are entitled to indemnification under this Article 11 shall not be affected, notwithstanding (i) the making of this Agreement, (ii) any investigation or examination conducted by or on behalf of a Party with respect thereto, or (iii) the Closing hereunder.

ARTICLE 12

MISCELLANEOUS

12.1 Counterparts . This Agreement may be executed in counterparts, each of which shall be deemed an original instrument, but all such counterparts together shall constitute but one agreement.

12.2 Notices . All notices that are required or may be given pursuant to this Agreement shall be sufficient in all respects if given in writing, in English and by personal delivery (if signed for receipt), by certified or registered United States mail (postage prepaid, return receipt requested), by a nationally recognized overnight delivery service for next day delivery, transmitted via facsimile transmission or transmitted via electronic mail (following appropriate confirmation of receipt by return email, including an automated confirmation of receipt) and shall be deemed to have been made and the receiving Party charged with notice, when received except that if received after 5:00 p.m. (in the recipient’s time zone) on a Business Day or if received on a day that is not a Business Day, such notice, request or communication will not be effective until the next succeeding Business Day. All notices shall be addressed as follows:

 

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If to the Contributor Parties:
   Double Eagle Energy Permian Operating LLC
   1401 Ballinger, Suite 200
   Fort Worth, Texas 76102
   Attention:    Cody Campbell
   Telephone:    (817) 928-3260
   Facsimile:    (817) 334-0623
   Email:    ccampbell@depermian.com
With a copy to:    Vinson & Elkins L.L.P.
   666 Fifth Avenue
   26th Floor
   New York, NY 10103-0040
   Attention:    James Fox
   Telephone:    (212) 237-0131
   Facsimile:    (917) 849-5328
   Email:    jfox@velaw.com
Or, following the Closing, to Contributor Representative:
   Double Eagle Energy HoldCo LLC
   1401 Ballinger, Suite 200
   Fort Worth, Texas 76102
   Attention:    Cody Campbell
   Telephone:    (817) 928-3260
   Facsimile:    (817) 334-0623
   Email:    ccampbell@depermian.com
With a copy to:    Vinson & Elkins L.L.P.
   666 Fifth Avenue
   26th Floor
   New York, NY 10103-0040
   Attention:    James Fox
   Telephone:    (212) 237-0131
   Facsimile:    (917) 849-5328
   Email:    jfox@velaw.com

 

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If to Acquiror Parties:
   Parsley Energy, LLC
   303 Colorado Street
   Suite 3000
   Austin, Texas 78701
   Attention:    Michael W. Hinson, Senior Vice President –
   Corporate Development
   Telephone:    (737) 704-2337
   Email:    mhinson@parsleyenergy.com
With a copy to (which shall not constitute notice):
   Bracewell LLP
   711 Louisiana Street, Suite 2300
   Houston, Texas 77002
   Attention:    W. James McAnelly III
   Telephone:    713-221-1194
   Email:    James.McAnelly@bracewelllaw.com

Either Party may change its address for notice by notice to the other in the manner set forth above. All notices shall be deemed to have been duly given at the time of receipt by the Party to which such notice is addressed.

12.3 Expenses . Except as otherwise provided in this Agreement, all expenses incurred by the Contributor Parties in connection with or related to the authorization, preparation or execution of this Agreement, and the Exhibits and Schedules hereto and thereto, and all other matters related to the Closing, including all fees and expenses of counsel, accountants and financial advisers employed by the Contributor Parties, shall be borne solely and entirely by the Contributor Parties, and all such expenses incurred by Acquiror Parties shall be borne solely and entirely by Acquiror Parties.

12.4 Governing Law . This Agreement and the legal relations between the Parties shall be governed by and construed in accordance with the laws of the State of Texas, without regard to principles of conflicts of laws that would direct the application of the laws of another jurisdiction.

12.5 Dispute Resolution . Each Party consents to personal jurisdiction in any action brought in the United States federal courts located in the State of Texas with respect to any dispute, claim or controversy arising out of or in relation to or in connection with this Agreement, and each of the Parties agrees that any action instituted by it against the other with respect to any such dispute, controversy or claim (except to the extent a dispute, controversy, or claim arising out of or in relation to or in connection with title matters pursuant to Section 3.10 , or the determination of adjustments to the Unadjusted Purchase Price pursuant to Section 8.4(b) is referred to an expert pursuant to those Sections) will be instituted exclusively in the United States District Court for the Southern District of Texas. Each Party (a) irrevocably submits to the exclusive jurisdiction of such courts, (b) waives any objection to laying venue in any such

 

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action or proceeding in such courts, (c) waives any objection that such courts are an inconvenient forum or do not have jurisdiction over it, and (d) agrees that service of process upon it may be effected by mailing a copy thereof by registered mail (or any substantially similar form of mail), postage prepaid, to it at its address specified in Section 12.2 . The foregoing consents to jurisdiction and service of process shall not constitute general consents to service of process in the State of Texas for any purpose except as provided herein and shall not be deemed to confer any rights on any Person other than the Parties to this Agreement. THE PARTIES HEREBY WAIVE TRIAL BY JURY IN ANY ACTION, PROCEEDING OR COUNTERCLAIM BROUGHT BY ANY PARTY AGAINST ANOTHER IN ANY MATTER WHATSOEVER ARISING OUT OF OR IN RELATION TO OR IN CONNECTION WITH THIS AGREEMENT. FURTHER, NOTHING HEREIN SHALL DIVEST A COURT OF COMPETENT JURISDICTION OF THE RIGHT AND POWER TO GRANT A TEMPORARY RESTRAINING ORDER, TO GRANT TEMPORARY INJUNCTIVE RELIEF, OR TO COMPEL SPECIFIC PERFORMANCE OF ANY DECISION OF AN ARBITRAL TRIBUNAL MADE PURSUANT TO THIS PROVISION .

12.6 Captions . The captions in this Agreement are for convenience only and shall not be considered a part of or affect the construction or interpretation of any provision of this Agreement.

12.7 Waivers . Any failure by any Party to comply with any of its obligations, agreements or conditions herein contained may be waived by the Party to whom such compliance is owed by an instrument signed by the Party to whom compliance is owed and expressly identified as a waiver, but not in any other manner. No waiver of, or consent to a change in, any of the provisions of this Agreement shall be deemed or shall constitute a waiver of, or consent to a change in, other provisions hereof (whether or not similar), nor shall such waiver constitute a continuing waiver unless otherwise expressly provided.

12.8 Assignment . No Party shall assign or otherwise transfer all or any part of this Agreement to any third Person other than an Affiliate, nor shall any Party delegate any of its rights or duties hereunder (including by change of control, merger, consolidation, or stock purchase) to any third Person other than an Affiliate, without the prior written consent of the other Party and any transfer or delegation made without such consent shall be void. Subject to the foregoing, this Agreement shall be binding upon and inure to the benefit of the Parties and their respective successors and assigns. Notwithstanding the foregoing, Acquiror may, by providing written notice to Contributor, but without Contributor’s consent, assign its rights and delegate its duties hereunder in whole (but not in part) to an Affiliate of Acquiror; provided, however, such assignment shall not be permitted if it would reasonably be anticipated to increase the liability of any Contributing Group Member with respect to Taxes.

12.9 Entire Agreement . This Agreement and the documents to be executed hereunder and the Exhibits and Schedules attached hereto constitute the entire agreement among the Parties pertaining to the subject matter hereof, and supersede all prior agreements, understandings, negotiations and discussions, whether oral or written, of the Parties pertaining to the subject matter hereof. In entering into this Agreement, neither Party has relied on any statement, representation, warranty, covenant, or agreement of the other Party or its representatives other than those expressly contained in this Agreement.

 

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12.10 Amendment . This Agreement may be amended or modified only by an agreement in writing signed by the Contributor Parties and the Acquiror Parties and expressly identified as an amendment or modification.

12.11 No Third-Person Beneficiaries . Nothing in this Agreement shall entitle any Person other than the Acquiror Parties and the Contributor Parties to any claim, cause of action, remedy or right of any kind, except the rights expressly provided to the Persons described in Section 6.4 , Section 9.6 and Section 11.2(h) .

12.12 Severability . If any provision of this Agreement, or any application thereof, is held invalid, illegal or unenforceable in any respect under any Law, this Agreement shall be reformed to the extent necessary to conform, in each case consistent with the intention of the Parties, to such Law, and, to the extent such provision cannot be so reformed, then such provision (or the invalid, illegal or unenforceable application thereof) shall be deemed deleted from (or prohibited under) this Agreement, as the case may be, and the validity, legality and enforceability of the remaining provisions contained herein (and any other application of such provision) shall not in any way be affected or impaired thereby.

12.13 Time of the Essence . Time is of the essence in this Agreement. If the date specified in this Agreement for giving any notice or taking any action is not a Business Day (or if the period during which any notice is required to be given or any action taken expires on a date which is not a Business Day), then the date for giving such notice or taking such action (and the expiration of such period during which notice is required to be given or action taken) shall be the next day which is a Business Day.

12.14 References . In this Agreement: (a) references to any gender includes a reference to all other genders; (b) references to the singular includes the plural, and vice versa; (c) reference to any Article or Section means an Article or Section of this Agreement; (d) reference to any Exhibit or Schedule means an Exhibit or Schedule to this Agreement, all of which are incorporated into and made a part of this Agreement; (e) unless expressly provided to the contrary, “hereunder”, “hereof”, “herein” and words of similar import are references to this Agreement as a whole and not any particular Section or other provision of this Agreement; (f) references to “$” or “dollars” means United States Dollars; (g) “include” and “including” mean include or including without limiting the generality of the description preceding such term; and (h) reference to “ Exhibit A ” means Exhibit A-1 through Exhibit A-4 , collectively.

12.15 Construction . Acquiror is capable of making such investigation, inspection, review and evaluation of the Company Group Interests as a prudent purchaser would deem appropriate under the circumstances, including with respect to all matters relating to the Company Group Interests, their value, operation and suitability. Contributor and Acquiror Parties have had the opportunity to exercise business discretion in relation to the negotiation of the details of the transaction contemplated hereby. This Agreement is the result of arm’s-length negotiations from equal bargaining positions. It is expressly agreed that this Agreement shall not be construed against any Party, and no consideration shall be given or presumption made, on the basis of who drafted this Agreement or any particular provision thereof.

 

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12.16 Limitation on Damages . Notwithstanding anything to the contrary contained herein, none of the Acquiror Parties, the Contributor Parties, or any of their respective Affiliates shall be entitled to consequential, special, or punitive damages in connection with this Agreement and the transactions contemplated hereby (other than consequential, special, or punitive damages suffered by third Persons for which responsibility is allocated between the Parties in this Agreement) and each of the Acquiror Parties and the Contributor Parties, for itself and on behalf of its Affiliates, hereby expressly waives any right to consequential, special, or punitive damages in connection with this Agreement and the transactions contemplated hereby (other than consequential, special, or punitive damages suffered by third Persons for which responsibility is allocated between the Parties in this Agreement).

12.17 Contributor Representative .

(a) The Contributor Representative is hereby designated and appointed, and the Contributor Representative hereby agrees to serve, as agent and attorney-in-fact, following the Closing and the Liquidations, for each member of DEEP and their successors and assigns (collectively, the “ Members ” and each, a “ Member ”, and together with Contributor, the “ Represented Persons ”), with full power and authority to take any and all actions that the Contributor Representative believes are necessary or appropriate to consummate the Transactions contemplated by this Agreement, following the Closing and the Liquidations, for and on behalf of the Represented Persons as fully as if each Represented Person was acting on its own behalf, including (without limitation) full power and authority on such Represented Person’s behalf to: (i) establish a segregated bank account (the “ Member Fund ”) to hold an amount of cash equal to (A) five percent (5%) of the cash portion of the Adjusted Purchase Price as set forth in the Preliminary Settlement Statement as agreed by the Parties pursuant to Section 8.4(a) (the “ Cash Reserve ”) to purchase New Purchased Leases and New Wells (including any costs or expenses related thereto), plus (B) $500,000 (the “ Contributor Rep Expense Fund ”) to cover and reimburse reasonable out-of-pocket fees and expenses incurred by the Contributor Representative for its obligations in connection with this Agreement, which amounts shall be set aside by Contributor from the Cash Closing Payment received by Contributor pursuant to Section 8.3(a) ; provided , however , that to the extent that the amount of cash in the Contributor Rep Expense Fund is insufficient to cover any out-of-pocket fees and expenses incurred by the Contributor Representative pursuant to Schedule 6.13 , the Contributor Representative may use cash in the Cash Reserve to satisfy any such shortfall; (ii) following the Closing, deposit the Cash Reserve and the Contributor Rep Expense Fund in the Member Fund; (iii) negotiate, defend, dispute, contest, assert, compromise and settle all claims and matters arising under this Agreement following the Closing; (iv) interpret all of the terms and provisions of this Agreement and each other Transaction Agreement (other than the Registration Rights and Lock-Up Agreement and the LLC Agreement) and negotiate, consent to, execute and deliver any amendment, waiver or consent of or under this Agreement, the Defect Escrow Agreement and the Indemnity Holdback Escrow Agreement following the Closing; (v) authorize, negotiate, compromise, settle, agree to and otherwise handle any adjustments to the Unadjusted Purchase Price under this Agreement; (vi) use all or any portion of the Cash Reserve to fund any transactions (and any costs or expenses related thereto) contemplated by Schedule 6.13 in accordance with the terms thereof; (vii) use the Member Fund as a source of reimbursement for all reasonable out-of-pocket fees and expenses and other obligations of, or incurred by, the Contributor Representative in connection with the exercise by the Contributor Representative of

 

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its respective rights or the performance of its duties under this Agreement; (viii) agree to, negotiate, enter into settlements and compromises of, and comply with judgments of courts or other Governmental Authorities and awards of arbitrators with respect to any claims for indemnification by or against any member of Acquiror Group, in each case, relating to this Agreement or any other Transaction Agreement (other than the Registration Rights and Lock-Up Agreement and the LLC Agreement); (ix) agree to, negotiate, enter into settlements and compromises of, and comply with judgments of courts or other Governmental Authorities and awards of arbitrators with respect to any claims arising out of or relating to Title Defects under this Agreement following the Closing; (x) make, execute, and deliver all other contracts, orders, receipts, notices, requests, instructions, certificates, letters and other writings as the Contributor Representative may deem necessary and proper in connection with Contributor’s obligations under this Agreement or any other Transaction Agreement (other than the Registration Rights and Lock-Up Agreement and the LLC Agreement) following the Closing, or to effect any of the foregoing; (xi) disburse the Cash Reserve, the Contributor Rep Expense Fund, the Escrowed Defect Units and the Indemnity Holdback Units to the Represented Persons in accordance with the terms of that certain Member Representative Agreement by and among Contributor Representative and the Members; (xii) give and receive notices and communications to accept service of process on behalf of the Represented Persons pursuant to Section 12.5 ; (xiii) take such actions and make such filings as the Contributor Representative deems necessary or appropriate in connection with the Liquidations of each of Contributor, Member LLC and DEEP; (xiv) take any and all other actions specified or contemplated by this Agreement following the Closing, and to engage counsel, accountants or other agents in connection with the foregoing matters; and (xv) take all actions following the Closing that are either (A) necessary or appropriate in the judgment of the Contributor Representative for the accomplishment of the foregoing or (B) specifically mandated by this Agreement, in each case, in accordance with the terms of this Agreement or in furtherance of the Transactions contemplated by this Agreement; provided , however , that the Contributor Representative (acting as such) shall not take any action or enter into any agreements or settlements that would (x) disproportionately affect any Represented Person in relation to any other Represented Person that had been a Series A Member of DEEP or (y) result in any liability to a Represented Person other than liabilities to be satisfied out of the Member Fund, the Defect Escrow Account and the Indemnity Holdback Escrow Account without the prior consent of such Represented Person. Notices or communications to or from the Contributor Representative shall constitute notice to or from the Represented Persons for all purposes under this Agreement except where the context otherwise requires. The Contributor Representative shall provide notices or communications received by it on behalf of the Represented Persons promptly and in any case no more than three (3) Business Days after receipt. In addition, the Parties, the Contributor Representative and the Members acknowledge and agree that, from and after the Closing, the Contributor Representative shall assume the obligation to perform all covenants of the Contributor under this Agreement, the Defect Escrow Agreement and the Indemnity Holdback Escrow Agreement. For the avoidance of doubt, the Parties acknowledge that all limitations of liability applicable to the Contributor, including Section 8.5(b) and Section 11.3 , shall also apply to the Contributor Representative and the Contributor Representative shall bear no greater liability than Contributor under this Agreement.

(b) With the prior written consent of (a) one member of the VEP Group (as defined in the Second Amended and Restated Limited Liability Company Agreement of DEEP, dated as of November 7, 2016 (the “ DEEP LLC Agreement ”), and (b) one member of the

 

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Magnetar Group (as defined in the DEEP LLC Agreement), the Contributor Representative may delegate its authority as Contributor Representative to any one of the Members for a fixed or indeterminate period of time upon not fewer than ten (10) Business Days’ prior written notice to Acquiror in accordance with Section 12.2 and delivery to Acquiror of a written agreement of such successor Contributor Representative to be bound by the terms of this Section 12.17 . Each successor Contributor Representative has all of the power, authority, rights and privileges conferred by this Agreement upon the original Contributor Representative, and the term “Contributor Representative” as used in this Agreement includes any successor Contributor Representative.

(c) A decision, act, consent or instruction of the Contributor Representative in accordance with the terms of this Agreement constitutes a decision, act, consent or instruction, as applicable, of the Represented Persons (except where the context otherwise requires or the consent of the Represented Persons is required and has not been obtained) and is final, binding and conclusive upon the Represented Persons, and any Person dealing with the Contributor Representative is entitled to rely on such decision, act, consent or instruction of the Contributor Representative as being the decision, act, consent or instruction of the Represented Persons.

(d) This appointment and grant of power and authority by the Represented Persons to the Contributor Representative pursuant to this Section 12.17 is coupled with an interest, is in consideration of the mutual covenants made in this Agreement, is irrevocable and may not be terminated by the act of any Member or by operation of Laws, whether upon the death or incapacity of any Member, or by the occurrence of any other event.

(e) In the event that the Service Provider (as defined in the Transition Services Agreement) is an entity that is not a controlled Affiliate of John Sellers or Cody Campbell, either individually or collectively, the Contributor Representative shall cause the Service Provider to be subject to the restrictions set forth in Sections 2 and 3 of the Covenant Agreement, dated as of the date hereof, by and among Parsley Energy, LLC and the “Executives” listed as parties thereto (the “ Covenant Agreement ”), in accordance with the terms thereof, as though the Service Provider were an “Executive” for purposes of those sections; provided , however , that notwithstanding anything to the contrary in this Agreement or the Covenant Agreement, the foregoing shall not apply to any activity or action by (i) Apollo Natural Resources Partners, L.P. (“ ANRP I ”), (ii) Apollo Natural Resources Partners II, L.P. (“ ANRP II ”), (iii) any affiliate of ANRP I or ANRP II, or (iv) any portfolio company owned, operated, managed or controlled by any of the foregoing.

12.18 Recourse Only Against Parties . All claims, obligations, liabilities, or causes of action (whether in contract or in tort, in law or in equity, or granted by statute) that may be based upon, in respect of, arise under, out or by reason of, be connected with, or relate in any manner to this Agreement, or the negotiation, execution, or performance of this Agreement (including any representation or warranty made in, in connection with, or as an inducement to, this Agreement), may be made only against (and are expressly limited to) the entities that are expressly identified as parties in the preamble to this Agreement or any successor or permitted assign of any such Parties (“ Contracting Parties ”). No Person who is not a Contracting Party, including without limitation any director, officer, employee, incorporator, member, partner, manager, stockholder, Affiliate, agent, attorney, or representative of, and any financial advisor or lender to, any

 

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Contracting Party, or any director, officer, employee, incorporator, member, partner, manager, stockholder, Affiliate, agent, attorney, or representative of, and any financial advisor or lender to, any of the foregoing (“ Nonparty Affiliates ”), shall have any liability (whether in contract or in tort, in law or in equity, or granted by statute) for any claims, causes of action, obligations, or liabilities arising under, out of, in connection with, or related in any manner to this Agreement or based on, in respect of, or by reason of this Agreement or its negotiation, execution, performance, or breach; and, to the maximum extent permitted by law, each Contracting Party hereby waives and releases all such liabilities, claims, causes of action, and obligations against any such Nonparty Affiliates. Without limiting the foregoing, to the maximum extent permitted by law, (a) each Contracting Party hereby waives and releases any and all rights, claims, demands, or causes of action that may otherwise be available at law or in equity, or granted by statute, to avoid or disregard the entity form of a Contracting Party or otherwise impose liability of a Contracting Party on any Nonparty Affiliate, whether granted by statute or based on theories of equity, agency, control, instrumentality, alter ego, domination, sham, single business enterprise, piercing the veil, unfairness, undercapitalization, or otherwise; and (b) each Contracting Party disclaims any reliance upon any Nonparty Affiliates with respect to the performance of this Agreement or any representation or warranty made in, in connection with, or as an inducement to this Agreement.

 

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IN WITNESS WHEREOF, this Agreement has been signed by each of the Parties as of the date first above written.

 

CONTRIBUTOR:
DOUBLE EAGLE ENERGY PERMIAN OPERATING LLC
By:  

/s/ Cody Campbell

Name:   Cody Campbell
Title:   CO-CEO
CONTRIBUTOR PARENT:
DOUBLE EAGLE ENERGY PERMIAN LLC
By:  

/s/ Cody Campbell

Name:   Cody Campbell
Title:   CO-CEO
DOUBLE EAGLE ENERGY PERMIAN MEMBER LLC
By:  

/s/ Cody Campbell

Name:   Cody Campbell
Title:   CO-CEO
And, solely for the purposes of Section 12.17,
CONTRIBUTOR REPRESENTATIVE:
DOUBLE EAGLE ENERGY HOLDCO LLC
By:  

/s/ Cody Campbell

Name:   Cody Campbell
Title:   CO-CEO

S IGNATURE P AGE TO C ONTRIBUTION A GREEMENT


ACQUIROR:
PARSLEY ENERGY, LLC
By Parsley Energy Inc., its managing member
By:  

/s/ Bryan Sheffield

Name:   Bryan Sheffield
Title:   Chief Executive Officer
ACQUIROR PARENT:
PARSLEY ENERGY, INC.
By:  

/s/ Bryan Sheffield

Name:   Bryan Sheffield
Title:   Chief Executive Officer

S IGNATURE P AGE TO C ONTRIBUTION A GREEMENT

Exhibit 23.1

CONSENT OF INDEPENDENT AUDITORS

We consent to the reference to our firm under the caption “Experts” in the Registration Statements (Form S-3 No. 333-204766 and S-8 333-196295), including all amendments thereto, of Parsley Energy, Inc. for the registration of its Class A common stock and to the incorporation by reference therein of our report dated February 4, 2017, with respect to the financial statements of Double Eagle Energy Permian LLC, included in the Current Report on Form 8-K dated February 7, 2017, both filed with the Securities and Exchange Commission.

 

/s/ Ernst & Young LLP

Fort Worth, TX

February 7, 2017

Exhibit 23.2

CONSENT OF INDEPENDENT AUDITORS

We consent to the reference to our firm under the caption “Experts” in the registration statements (Form S-3 No. 333-204766 and Form S-8 No. 333-196295), including any amendments thereto, of Parsley Energy, Inc. for the registration of its Class A common stock and to the incorporation by reference therein of our report dated February 4, 2017, with respect to the financial statements of Double Eagle Energy Permian LLC, included in the Current Report on Form 8-K dated February 7, 2017, both filed with the Securities and Exchange Commission.

 

/s/ Weaver and Tidwell L.L.P.

Fort Worth, Texas

February 7, 2017

Exhibit 23.3

CONSENT OF INDEPENDENT PETROLEUM ENGINEERS AND GEOLOGISTS

We hereby consent to the references to our firm, in the context in which they appear, and to the references to and the incorporation by reference of our audit letter dated February 3, 2017, included in this Current Report on Form 8-K of Parsley Energy, Inc. (the “Company”). We also hereby consent to the incorporation by reference of the references to our firm, in the context in which they appear, and of our audit letter dated February 3, 2017, into the Company’s registration statements on Form S-8 (File No. 333-196295) and Form S-3 (File No. 333-204766), including any amendments thereto, in accordance with the requirements of the Securities Act of 1933, as amended.

 

NETHERLAND, SEWELL & ASSOCIATES, INC.
By:  

/s/ C.H. (Scott) Rees III, P.E.

  C.H. (Scott) Rees III, P.E.
  Chairman and Chief Executive Officer

Dallas, Texas

February 7, 2017

 

Please be advised that the digital document you are viewing is provided by Netherland, Sewell & Associates, Inc. (NSAI) as a convenience to our clients. The digital document is intended to be substantively the same as the original signed document maintained by NSAI. The digital document is subject to the parameters, limitations, and conditions stated in the original document. In the event of any differences between the digital document and the original document, the original document shall control and supersede the digital document.

EXHIBIT 23.4

 

 

LOGO

CONSENT OF INDEPENDENT PETROLEUM ENGINEERS AND GEOLOGISTS

As independent petroleum engineers, we hereby consent to the incorporation by reference in Parsley Energy, Inc’s registration statements on Form S-8 (File No. 333-196295) and Form S-3 (File No. 333-204766), including any amendments thereto, relating to our reserves reports of Double Eagle Energy Permian LLC’s proved oil and natural gas reserves estimates and associated revenues as of December 31, 2015 and 2014, and the inclusion of our corresponding report letters, both dated January 30, 2017, included in or made a part of this Current Report on Form 8-K. We also consent to the references to our firm contained in the Registration Statement, including under the caption “Experts.”

 

CAWLEY, GILLESPIE & ASSOCIATES, INC.

/s/ Cawley, Gillespie & Associates, Inc.

Fort Worth, Texas

February 7, 2017

Exhibit 99.1

 

LOGO   NEWS RELEASE

PARSLEY ENERGY ANNOUNCES CONSOLIDATING MIDLAND BASIN ACQUISITION, REVISES 2017 CAPITAL PROGRAM AND OPERATING GUIDANCE, AND PROVIDES UPDATES ON 4Q16 OPERATIONS, YEAR-END 2016 RESERVES, AND RECENT HEDGING ACTIVITY

AUSTIN, Texas, February  7, 2017 – Parsley Energy, Inc. (NYSE: PE) (“Parsley,” “Parsley Energy,” or the “Company”) today announced that it has entered into an agreement to acquire certain undeveloped acreage and producing oil and gas properties in the core of the Midland Basin from Double Eagle Energy Permian LLC (“Double Eagle”) for an aggregate purchase price of approximately $2.8 billion, subject to purchase price adjustments and customary closing conditions. Upon completion, the pending acquisition will add approximately 71,000 net acres to the Company’s Midland Basin acreage portfolio, bringing total Permian Basin net acreage to approximately 227,000 acres. Parsley intends to increase drilling and completion activity on the Company’s expanded asset base and, as a result, is updating 2017 capital plans and operating guidance to reflect increased capital investment and associated production growth. Herein Parsley also provides updates on preliminary 4Q16 and full-year 2016 operational results, year-end 2016 reserves, and recent hedging activity.

 

LOGO

 

 

1


Acquisition Highlights

 

    Approximately 71,000 net leasehold acres

 

    Estimated net production of approximately 3,600 Boe per day as of January 1, 2017

 

    23 drilled uncompleted wells, variously targeting the Lower Spraberry, Middle Spraberry, Wolfcamp A, and Wolfcamp B formations, with an average lateral length of approximately 8,400 feet, valued at approximately $75-100 MM in aggregate

 

    Approximately 3,300 net horizontal drilling locations, including approximately 1,800 net locations in high priority target intervals (Lower Spraberry, Wolfcamp A, Wolfcamp B)

 

    Average lateral length of approximately 6,600 feet on acquired horizontal drilling locations; more than 40% of acquired horizontal drilling locations have lateral lengths of 7,500 feet or more

 

    Operating control on 80% of net horizontal drilling locations

 

    Incremental value potential through ongoing acreage trades, bolt-on acquisitions, and working interest buyouts; Double Eagle to assist with asset operation and handoff, as well as acreage trades and purchases after closing

 

    Consideration consists of approximately $1.4 billion of cash and approximately 39.4 million units of Parsley Energy, LLC (together with a corresponding number of shares of Parsley Energy class B common stock) valued at approximately $1.4 billion; Parsley intends to finance the cash portion of the consideration through equity and debt offerings announced concurrently with the acquisition

 

    Scheduled to close on or before April 20, 2017, subject to the satisfaction of customary closing conditions

Pro Forma Company Highlights

 

    Approximately 227,000 net leasehold acres in the Permian Basin

 

    Approximately 179,000 net leasehold acres in the Midland Basin, representing the second-largest Midland Basin net acreage position among publicly traded E&P companies

 

    Approximately 7,900 net horizontal drilling locations, including approximately 4,300 net locations in well delineated, high value target intervals (Wolfcamp A, Wolfcamp B, and Lower Spraberry in the Midland Basin; Upper Wolfcamp in the Southern Delaware Basin)

 

    Sufficient acreage footprint to support more than 20 rigs focused on horizontal development

“We are pleased to solidify Parsley’s position as a leading Permian operator through our largest acquisition to date,” stated Bryan Sheffield, Chairman and Chief Executive Officer of Parsley Energy. “This transaction maintains our focus on core of the core acreage with the most favorable reservoir characteristics and positions us for years of production growth at the low end of the cost curve. The infusion of high quality drilling locations substantially increases our peak production potential and extends our inventory of drilling locations while enhancing the quality of that inventory. We believe this transaction sets us apart from peer companies on the basis of the size and quality of our acreage position in what we consider the most desirable basin in the country.”

John Sellers and Cody Campbell, Co-CEOs of Double Eagle, commented, “With many possible paths for the next phase in the evolution and development of Double Eagle’s assets, we were excited to negotiate a transaction with Parsley given the Company’s history of efficient growth and of enhancing the value of its asset base through the same types of creative transactions it took to build Double Eagle’s portfolio.” Greg Beard, Head of Natural Resources and Senior Partner at Apollo Global Management, added, “On behalf of Apollo and Double Eagle’s other financial sponsors, Post Oak Energy Capital and Magnetar Capital, we look forward to working with Parsley Energy as the Company develops the prized assets the Double Eagle team has expertly assembled in the true core of the Midland Basin. We believe Parsley’s record of strong operational performance and the Company’s complementary asset base make Parsley the ideal company to deliver the tremendous value associated with these assets.”

 

2


Fourth Quarter and Full Year 2016 Operations Update 1

The Company expects to report 4Q16 net production of 44.8-45.2 MBoe per day, up approximately 5% at the midpoint versus 3Q16 net production, placing full-year 2016 average production within the annual guidance range.

The Company expects to report 4Q16 capital expenditures of $155-$160 MM, translating to full-year 2016 capital expenditures that fall within the annual guidance range. Parsley expects to report unit costs near the low end of annual guidance ranges.

The Company plans to release detailed fourth quarter and full-year 2016 results on February 23, 2017 and to discuss these results on a conference call scheduled for February 24, 2017, details of which can be found below. The following table shows revised expectations for full-year 2016 results based on preliminary 4Q16 results:

 

     2016E      2016E  
     (Prior)      (Updated)  

Production

     

Annual production (MBoe/d)

     37-39         38.1-38.3   

Capital Program

     

Total development expenditures ($MM)

     $460-$510         $493-$499   

Activity

     

Gross operated horizontal completions

     80-90         79   

Average lateral length

     ~7,000’         ~7,400’   

Average working interest

     85%-95%         96%   

Unit Costs

     

Lease operating expenses ($/Boe)

     $4.25-$4.75         $4.10-$4.30   

Cash general and administrative expenses ($/Boe)

     $5.00-$5.50         $5.00-$5.25   

Updated 2017 Capital Program and Operational Guidance 2

Prompted by the pending acreage acquisition and relative to the activity contemplated by its previously disclosed capital program, Parsley intends to add four rigs by the end of 2017, translating to approximately 40 incremental horizontal well spuds in 2017, approximately 10 of which are expected to be put on production this year. All of the incremental wells would be located in the Midland Basin. While the majority of the production impact associated with incremental drilling and completion activity would occur in 2018, Parsley is raising 2017 net daily production guidance by 5 MBoe per day to a range of 62-68 MBoe per day, and is likewise increasing expected 4Q17 production from 70-80 MBoe per day to 75-85 MBoe per day.

 

1   The preliminary 4Q16 estimates set forth herein are derived from internal records and are based on the most current information available to the Company’s management. The Company’s normal reporting processes with respect to such preliminary operational data have not been fully completed and, during the course of its review process on these preliminary estimates, the Company could identify items that would require it to make adjustments and which could affect its final results. Any such adjustments could be material.
2   All figures represent Company expectations and all except reference to 4Q17 net production refer to full-year 2017 totals or averages.

 

3


Historical and Projected Horizontal Rig Activity 3

 

     1Q16      2Q16      3Q16      4Q16      1Q17      2Q17      3Q17      4Q17  

Rig Count – Prior

     6         6         6         7         10         10         10         10   

Rig Count – Updated

     6         6         6         7         10         11         12         14   

Changes to annual guidance ranges are shown in the following table:

 

     2017E      2017E *  
     (Prior)      (Updated)  

Production

     

Annual production (MBoe/d)

     57-63         62-68   

% Oil

     68%-73%         68%-73%   

Capital Program

     

Drilling and completion ($MM)

     $630-$750         $840-$960   

Infrastructure and other ($MM)

     $120-$150         $160-$190   

Total development expenditures ($MM)

     $750-$900         $1,000-$1,150   

Activity

     

Gross operated horizontal completions

     120-140         130-150   

Midland Basin

     85-95         95-105   

Delaware Basin

     35-45         35-45   

Average lateral length

     ~8,000’         ~8,000’   

Gross operated vertical completions

     0         5-10   

Average working interest

     85%-95%         85%-95%   

Unit Costs

     

Lease operating expenses ($/Boe)

     $4.00-$4.75         $4.00-$4.75   

Cash general and administrative expenses ($/Boe)

     $4.50-$5.25         $4.50-$5.25   

Production and ad valorem taxes (as a % of revenue)

     6.5%-7.5%         6.5%-7.5%   

 

* These estimates are based on our current planned capital expenditures, drilling activity, and well results, as well as our current expected unit costs for 2017. Achieving these production estimates and maintaining the required drilling activity to achieve these estimates will depend on the availability of capital, regulatory approval, commodity prices, drilling and completion costs, actual drilling results, and other factors. To the extent any of these factors changes adversely, we may not be able to achieve these production and drilling results.

The increase in expected capital expenditures versus previous guidance is associated with the additional horizontal wells noted above, deployment of a vertical rig to hold Double Eagle acreage to be acquired, non-operated activity and associated capital expenditures on acreage to be acquired, service and equipment cost inflation on incremental activity relative to costs on previously anticipated activity, and expenses associated with the integration of new assets.

 

 

3   While certain of Parsley’s previous disclosures have referenced only those rigs tasked to drill both the vertical and lateral portions of a horizontal well, the table above and associated discussion contemplate all rigs utilized for horizontal drilling activity, some of which may be dedicated to and purposed for certain segments of the wellbore. “Spudder” rigs are excluded from the counts above.

 

4


Hedging Update

In view of the anticipated production growth associated with additional drilling and completion activity on an expanded asset base, Parsley has added meaningfully to and extended the duration of its oil hedge portfolio, thereby reducing the variability of its anticipated cash flows and enhancing the Company’s ability to execute its development and value creation objectives.

Open Oil Derivatives Positions

 

    1Q17     2Q17     3Q17     4Q17     1Q18     2Q18     3Q18     4Q18     1Q19     2Q19     3Q19     4Q19  

Put Spreads (MBbls/d)

    13.8        13.6        35.7        45.5        23.3        23.1        13.0        13.0           

Put Price ($/Bbl)

  $ 49.93      $ 49.93      $ 52.66      $ 52.80      $ 53.21      $ 52.14      $ 50.00      $ 50.00           

Short Put Price ($/Bbl)

  $ 36.14      $ 36.14      $ 41.80      $ 41.95      $ 41.43      $ 42.14      $ 40.00      $ 40.00           

Three Way Collars (MBbls/d)

              6.6        17.9        17.9        8.3        8.2        8.2        8.2   

Call Price ($/Bbl)

            $ 77.10      $ 76.57      $ 76.57      $ 80.40      $ 80.40      $ 80.40      $ 80.40   

Put Price ($/Bbl)

            $ 50.00      $ 50.00      $ 50.00      $ 50.00      $ 50.00      $ 50.00      $ 50.00   

Short Put Price ($/Bbl)

            $ 40.00      $ 40.00      $ 40.00      $ 40.00      $ 40.00      $ 40.00      $ 40.00   

Premium Realization ($ MM)

  ($ 4.9   ($ 4.9   ($ 14.2   ($ 17.8   ($ 9.5   ($ 8.0   ($ 6.3   ($ 6.3   ($ 1.5   ($ 1.5   ($ 1.5   ($ 1.5

Mid-Cush Basis Swaps (MBbls/d)

    11.3        11.3        12.2        12.2        1.0        1.0        1.0        1.0           

Swap Price ($/Bbl)

  ($ 1.00   ($ 1.00   ($ 1.05   ($ 1.05   ($ 0.95   ($ 0.95   ($ 0.95   ($ 0.95        

In addition to the hedge portfolio shown in the table above, Parsley expects to assume the following hedge positions upon completion of the pending acquisition of Midland Basin assets:

 

     1Q17      2Q17      3Q17     4Q17     1Q18     2Q18     3Q18     4Q18  

Collars (MBbls/d)

        1.5         4.0        4.0        3.0        3.0        3.0        3.0   

Long Put Price ($/Bbl)

      $ 47.00       $ 46.75      $ 46.75      $ 45.67      $ 45.67      $ 45.67      $ 45.67   

Short Call Price ($/Bbl)

      $ 56.15       $ 59.73      $ 59.98      $ 61.31      $ 61.31      $ 61.31      $ 61.31   

WTI Swaps (MBbls/d)

        1.0         0.5        0.5        0.5        0.5        0.5        0.5   

Strike Price ($/Bbl)

      $ 53.42       $ 55.00      $ 55.00      $ 55.00      $ 55.00      $ 55.00      $ 55.00   

Mid-Cush Basis Swaps (MBbls/d)

           4.5        4.5        3.5        3.5        3.5        3.5   

Swap Price ($/Bbl)

         ($ 0.86   ($ 0.86   ($ 0.90   ($ 0.90   ($ 0.90   ($ 0.90

Year-end 2016 Reserves

Parsley posted strong reserve growth in 2016. The Company’s proved reserves as of December 31, 2016 were 222.3 MMBoe and consist of 136.5 million barrels of oil, 223.6 billion cubic feet of natural gas, and 48.5 million barrels of natural gas liquids.

Proved Reserve Highlights

 

    Proved reserves increased 80% to 222.3 MMBoe, while proved developed reserves increased 106% to 106.1 MMBoe from year-end 2015 reserves

 

    Total reserves increased by 98.5 MMBoe as compared to 2016 production volumes of 14.0 MMBoe

 

    Proved developed reserves at year-end 2016 represent 48% of total proved reserves

 

    The Company voluntarily removed all of the remaining 18.4 MMBoe of economic reserves associated with potential vertical well activity over the next five years

 

    Pricing revisions account for 2.8 MMBoe of 3.8 MMBoe total revisions to proved reserve estimates

 

5


Changes in reserves for the year ended December 31, 2016 are summarized in the table below:

 

     (MMBoe)  

Balance, December 31, 2015

     123.8   

Additions

     98.7   

Acquisitions

     24.2   

Divestitures

     (6.6

Revisions

     (3.8

Production

     (14.0
  

 

 

 

Balance, December 31, 2016

     222.3   

Parsley’s internally-prepared estimated proved reserves were audited by Netherland, Sewell & Associates, the Company’s independent reserve engineer, as of December 31, 2016. These estimates have been prepared in accordance with the definitions and regulations of the U.S. Securities and Exchange Commission and conform to the FASB Accounting Standards Codification Topic 932, Extractive Activities – Oil and Gas. Prices used are based on 12-month unweighted arithmetic average of the first-day-of-the-month price for each month in the period January through December 2016. Adjusting for quality, transportation fees, and market differentials, the pricing is as follows: $39.36 per barrel of oil, $15.03 per barrel of NGL, and $2.23 per Mcf of gas. The estimate of the Company’s net reserves as of December 31, 2016 are summarized in the table below:

 

     Net Reserves  
     Oil (MMBbls)      Gas (Bcf)      NGL (MMBbls)      Total (MMBoe)  

PDP

     59.3         121.8         23.7         103.3   

PNP

     1.9         2.2         0.6         2.8   

PUD

     75.4         99.7         24.2         116.2   
  

 

 

    

 

 

    

 

 

    

 

 

 

Total Proved

     136.6         223.7         48.5         222.3   

Conference Call Information

Parsley Energy will host a conference call and webcast to discuss its results for the fourth quarter of 2016 on Friday, February 24, 2017 at 9:00 a.m. Eastern Time (8:00 a.m. Central Time). Participants should call 877-407-0672 (United States/Canada) or 412-902-0003 (International) 10 minutes before the scheduled time and request the Parsley Energy conference call. A telephone replay will be available shortly after the call through March 3, 2017 by dialing 877-660-6853 (United States/Canada) or 201-612-7415 (International). Conference ID: 13655145. A live broadcast will also be available on the internet at www.parsleyenergy.com under the “Investor Relations” section of the website.

Registration Statement

The Company has filed a registration statement (including a prospectus) with the SEC for the equity offering to which this communication relates. Before you invest, you should read the prospectus in that registration statement and other documents the Company has filed with the SEC for more complete information about the Company and the equity offering. You may get these documents for free by visiting EDGAR on the SEC Web site at www.sec.gov . Alternatively, the issuer, any underwriter or any dealer participating in the equity offering will arrange to send you the prospectus if you request it by contacting Credit Suisse Securities (USA) LLC, Attn: Prospectus Department, One Madison Avenue, New York, NY 10010 or Morgan Stanley & Co. LLC , Attn: Prospectus Department, 180 Varick Street, 2nd Floor, New York, NY 10014.

About Parsley Energy, Inc.

Parsley Energy, Inc. is an independent oil and natural gas company focused on the acquisition and development of unconventional oil and natural gas reserves in the Permian Basin in West Texas.

 

6


Forward Looking Statements

Certain statements contained in this news release constitute “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. These forward-looking statements represent Parsley Energy’s expectations or beliefs concerning future events, and it is possible that the results described in this news release will not be achieved. These forward-looking statements are subject to risks, uncertainties and other factors, many of which are outside of Parsley Energy’s control, which could cause actual results to differ materially from the results discussed in the forward-looking statements. Any forward-looking statement speaks only as of the date on which it is made, and, except as required by law, Parsley Energy does not undertake any obligation to update or revise any forward-looking statement, whether as a result of new information, future events or otherwise. New factors emerge from time to time, and it is not possible for Parsley Energy to predict all such factors. When considering these forward-looking statements, you should keep in mind the risk factors and other cautionary statements found in our filings with the SEC, including our Annual Report on Form 10-K. The risk factors and other factors noted in our SEC filings could cause our actual results to differ materially from those contained in any forward-looking statement.

Contact Information

Brad Smith, Ph.D., CFA

Senior Vice President, Corporate Strategy and Investor Relations

ir@parsleyenergy.com

(512) 505-5199

 

7

Exhibit 99.2

 

LOGO

NEWS RELEASE

Parsley Energy Announces Public Offering

of Class A Common Stock

AUSTIN, Texas, February 7, 2017—Parsley Energy, Inc. (NYSE: PE) (“Parsley Energy” or the “Company”) today announced that it has commenced an underwritten public offering of 36,000,000 shares of Class A common stock (the “Equity Offering”). The Company expects to grant the underwriters an option to purchase up to an additional 5,400,000 shares of Class A common stock from the Company.

Concurrently with the Equity Offering, Parsley Energy, LLC and Parsley Finance Corp., the Company’s consolidated subsidiaries, intend to offer to qualified institutional buyers and non-U.S. persons outside of the U.S., in an offering exempt from registration under the Securities Act of 1933, as amended, $350.0 million aggregate principal amount of senior notes due 2025 (the “Concurrent Notes Offering”). The Company will not guarantee the senior notes. The Equity Offering is not conditioned on the consummation of the Concurrent Notes Offering, and the Concurrent Notes Offering is not conditioned on the consummation of the Equity Offering.

Together with a portion of the net proceeds from the Concurrent Notes Offering, the Company intends to use the net proceeds of the Equity Offering to fund the cash portion of the purchase price for the acquisition of certain undeveloped acreage and producing oil and gas properties in the Midland Basin from Double Eagle Energy Permian LLC (the “Double Eagle Acquisition”). The Equity Offering is not conditioned on the consummation of the Double Eagle Acquisition. If the Double Eagle Acquisition is not consummated, or if there are any remaining net proceeds from the Equity Offering following its consummation, the Company intends to use such net proceeds to fund a portion of its capital program and for general corporate purposes, including potential future acquisitions.

Credit Suisse Securities (USA) LLC and Morgan Stanley are acting as joint lead bookrunners for the Equity Offering.

The Equity Offering is being made pursuant to an effective shelf registration statement, which has been filed with the Securities and Exchange Commission (the “SEC”) and became effective June 5, 2015. The Equity Offering will be made only by means of a preliminary prospectus supplement and the accompanying base prospectus, copies of which may be obtained on the SEC’s website at www.sec.gov. Alternatively, the joint lead bookrunners will arrange to send you the preliminary prospectus supplement and related base prospectus if you request them by contacting:

Credit Suisse Securities (USA) LLC

Attn: Prospectus Department

One Madison Avenue

New York, NY 10010

Telephone: 1-800-221-1037

newyork.prospectus@credit-suisse.com

Morgan Stanley & Co. LLC

Attn: Prospectus Department

180 Varick Street, 2 nd Floor

New York, NY 10014

This news release is neither an offer to sell nor a solicitation of an offer to buy any securities, nor shall there be any sale of any such securities in any state or jurisdiction in which such offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such state or jurisdiction.


About Parsley Energy, Inc.

Parsley Energy, Inc. is an independent oil and natural gas company focused on the acquisition and development of unconventional oil and natural gas reserves in the Permian Basin in West Texas.

Forward-Looking Statements

Certain statements contained in this news release constitute “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. These forward-looking statements represent Parsley Energy’s expectations or beliefs concerning future events, and it is possible that the results described in this news release will not be achieved. These forward-looking statements are subject to risks, uncertainties and other factors, many of which are outside of Parsley Energy’s control, which could cause actual results to differ materially from the results discussed in the forward-looking statements. Any forward-looking statement speaks only as of the date on which it is made, and, except as required by law, Parsley Energy does not undertake any obligation to update or revise any forward-looking statement, whether as a result of new information, future events or otherwise. New factors emerge from time to time, and it is not possible for Parsley Energy to predict all such factors. When considering these forward-looking statements, you should keep in mind the risk factors and other cautionary statements found in our filings with the SEC, including, but not limited to, our Annual Report on Form 10-K for the year ended December 31, 2015 and our subsequent Quarterly Reports on Form 10-Q and Current Reports on Form 8-K. The risk factors and other factors noted in our SEC filings could cause our actual results to differ materially from those contained in any forward-looking statement.

Contact Information

Brad Smith, Ph.D., CFA

Parsley Energy, Inc.

Senior Vice President, Corporate Strategy and Investor Relations

ir@parsleyenergy.com

(512) 505-5199

Source: Parsley Energy, Inc.

 

2

Exhibit 99.3

 

LOGO

NEWS RELEASE

Parsley Energy, LLC Announces $350 Million Private Placement of

Senior Unsecured Notes due 2025

AUSTIN, Texas, February 7, 2017— Parsley Energy, LLC (“Parsley”), a subsidiary of Parsley Energy, Inc. (NYSE: PE) (“Parsley Inc.”), and Parsley’s wholly owned subsidiary, Parsley Finance Corp., announced today that they have commenced, subject to market conditions and other factors, a private placement of $350.0 million in aggregate principal amount of senior unsecured notes due 2025 to eligible purchasers (the “Notes Offering”).

Concurrently with the Notes Offering, Parsley Inc. is offering 36,000,000 shares of its Class A common stock (or 41,400,000 shares if the option to purchase additional shares is exercised in full) in an underwritten public offering (the “Concurrent Equity Offering”). The shares of Class A common stock are being offered in the Concurrent Equity Offering by means of a separate prospectus supplement. The Notes Offering is not conditioned on the consummation of the Concurrent Equity Offering, and the Concurrent Equity Offering is not conditioned on the consummation of the Notes Offering.

Together with a portion of the net proceeds from the Concurrent Equity Offering, Parsley intends to use the net proceeds of the Notes Offering to fund the cash portion of the purchase price for the acquisition of certain undeveloped acreage and producing oil and gas properties in the Midland Basin from Double Eagle Energy Permian LLC (the “Double Eagle Acquisition”). The Notes Offering is not conditioned on the consummation of the Double Eagle Acquisition. If the Double Eagle Acquisition is not consummated, or if there are any remaining net proceeds from the Notes Offering following its consummation, Parsley intends to use such net proceeds to fund a portion of its capital program and for general corporate purposes, including potential future acquisitions.

The securities to be offered in the Notes Offering have not been registered under the Securities Act of 1933, as amended (the “Securities Act”), or any state securities laws and, unless so registered, may not be offered or sold in the United States except pursuant to an exemption from, or in a transaction not subject to, the registration requirements of the Securities Act and applicable state securities laws. Parsley plans to offer and sell the securities only to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to non-U.S. persons in transactions outside the United States pursuant to Regulation S under the Securities Act.

This news release does not constitute an offer to sell or the solicitation of an offer to buy the securities described herein, nor shall there be any sale of these securities in any jurisdiction in which such an offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such jurisdiction.

Forward-Looking Statements

Certain statements contained in this news release constitute “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. These forward-looking statements represent Parsley’s expectations or beliefs concerning future events, and it is possible that the results described in this news release will not be achieved. These forward-looking statements are subject to risks, uncertainties and other factors, many of which are outside of Parsley’s control, which could cause actual results to differ materially from the results discussed in the forward-looking statements. Any forward-looking statement speaks only as of the date on which it is made, and, except as required by law, Parsley does not undertake any obligation to update or revise any forward-looking statement, whether as a result of new information, future events or otherwise. New factors emerge from time to time, and it is not possible for Parsley to predict all such factors. When considering these forward-looking statements, you should keep in mind the risk factors and other cautionary statements found in Parsley Inc.’s filings with the SEC, including, but not limited to, Parsley Inc.’s Annual Report on Form 10-K for the year ended December 31, 2015 and its subsequent Quarterly Reports on Form 10-Q and Current Reports on Form 8-K. The risk factors and other factors noted in Parsley Inc.’s SEC filings could cause actual results to differ materially from those contained in any forward-looking statement.


Contact Information

Brad Smith, Ph.D., CFA

Parsley Energy, LLC

Senior Vice President, Corporate Strategy and Investor Relations

ir@parsleyenergy.com

(512) 505-5199

Source: Parsley Energy, LLC

Exhibit 99.4

 

LOGO

Financial Statements

As of December 31, 2014

and For the Year Then Ended


DOUBLE EAGLE ENERGY PERMIAN LLC

INDEX TO THE FINANCIAL STATEMENTS

 

     Page  

Independent Auditor’s Report

     3   

Balance Sheet at December 31, 2014

     4   

Statement of Operations For the Year Ended December 31, 2014

     5   

Statement of Changes in Members’ Equity For the Year Ended December 31, 2014

     6   

Statement of Cash Flows For the Year Ended December 31, 2014

     7   

Notes to the Financial Statements

     8   

Supplemental Information

     20   

 

2


LOGO

INDEPENDENT AUDITOR’S REPORT

The Members

Double Eagle Energy Permian LLC

We have audited the accompanying financial statements of Double Eagle Energy Permian LLC, which comprise the balance sheet as of December 31, 2014, and the related statements of operations, changes in members’ equity, and cash flows for the year then ended, and the related notes to the financial statements.

Management’s Responsibility for the Financial Statements

Management is responsible for the preparation and fair presentation of these financial statements in accordance with accounting principles generally accepted in the United States of America; this includes the design, implementation, and maintenance of internal control relevant to the preparation and fair presentation of financial statements that are free from material misstatement, whether due to fraud or error.

Auditor’s Responsibility

Our responsibility is to express an opinion on these financial statements based on our audit. We conducted our audit 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 financial statements are free from material misstatement.

An audit involves performing procedures to obtain audit evidence about the amounts and disclosures in the financial statements. The procedures selected depend on the auditor’s judgment, including the assessment of the risks of material misstatement of the financial statements, whether due to fraud or error. In making those risk assessments, the auditor considers internal control relevant to the entity’s preparation and fair presentation of the financial statements in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the entity’s internal control. Accordingly, we express no such opinion. An audit also includes evaluating the appropriateness of accounting policies used and the reasonableness of significant accounting estimates made by management, as well as evaluating the overall presentation of the financial statements.

We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion.

Opinion

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Double Eagle Energy Permian, LLC as of December 31, 2014, and the results of its operations and its cash flows for the year then ended in accordance with accounting principles generally accepted in the United States of America.

Change in Reporting Entity

As discussed in Note 1 to the financial statements, the 2014 financial statements reflect retrospective application related to the change in reporting entity. Our opinion is not modified with respect to this matter.

 

 

LOGO

WEAVER AND TIDWELL L.L.P.

Fort Worth, Texas

February 4, 2017

 

AN INDEPENDENT MEMBER OF BAKER TILLY INTERNATIONAL   WEAVER AND TIDWELL, L.L.P. CERTIFIED PUBLIC ACCOUNTANTS AND ADVISORS  

2821 WEST SEVENTH STREET,

SUITE 700, FORT WORTH, TX 76107

P: 817.332.7905 F:  817.429.5936

 

3


Double Eagle Energy Permian LLC

Balance Sheet at

December 31, 2014

 

Assets

  

Current assets:

  

Cash

   $ 3,053,173  

Accounts receivable

     485,678  

Other current assets

     10,017  
  

 

 

 

Total current assets

     3,548,868  

Property and equipment:

  

Oil and gas properties, successful efforts method of accounting:

  

Proved properties

     8,403,315  

Unproved properties

     12,240,179  
  

 

 

 

Total oil and gas properties

     20,643,494  

Less: Accumulated depreciation, depletion and amortization

     (963,044
  

 

 

 

Total oil and gas properties, net

     19,680,450  

Deferred financing fees

     5,643  
  

 

 

 

Total assets

   $ 23,234,961  
  

 

 

 

Liabilities and Members’ Equity

  

Current liabilities:

  

Accounts payable and accrued liabilities

   $ 1,657,418  

Accounts payable to related parties

     226,400  

Accrued oil and gas development expenditures

     1,003,244  
  

 

 

 

Total current liabilities

     2,887,062  

Deferred tax liability

     58,055  

Deferred lease acquisition costs

     740,000  

Asset retirement obligations

     6,789  

Commitments and contingencies

  

Members’ Equity

     19,543,055  
  

 

 

 

Total liabilities and members’ equity

   $ 23,234,961  
  

 

 

 

The accompanying notes are an integral part of these financial statements.

 

4


Double Eagle Energy Permian LLC

Statement of Operations

For the Year Ended December 31, 2014

 

Revenues:

  

Oil, natural gas and NGL sales

   $ 1,316,838   

Operating Expenses:

  

Lease operating expenses

     101,429   

Production and ad valorem taxes

     58,961   

Transportation and processing

     3,350   

Abandonments and dry hole costs

     477,261   

General and administrative

     775,143   

Depreciation, depletion and amortization

     963,044   

Gain on sale of oil and gas properties

     (8,128,323
  

 

 

 

Total costs and expenses

   $ (5,749,135
  

 

 

 

Operating income

   $ 7,065,973   

Texas margin tax

     58,055   
  

 

 

 

Net income

   $ 7,007,918   
  

 

 

 

The accompanying notes are an integral part of these financial statements.

 

5


Double Eagle Energy Permian LLC

Statement of Changes in Members’ Equity

For the Year Ended December 31, 2014

 

     Members’ Equity  

Balance at December 31, 2013

   $ 3,878,059   

Net income

     7,007,918   

Capital contributions

     19,323,803   

Capital distributions

     (11,500,000

Parent company net investment

     833,275   
  

 

 

 

Balance at December 31, 2014

   $ 19,543,055   
  

 

 

 

The accompanying notes are an integral part of these financial statements.

 

6


Double Eagle Energy Permian LLC

Statement of Cash Flows

For the Year Ended December 31, 2014

 

Cash flows from operating activities:

  

Net income

   $ 7,007,918   

Adjustments to reconcile net income to net cash provided by operating activities:

  

Depreciation, depletion and amortization

     963,044   

Texas margin tax expense

     58,055   

Gain on sale of oil and gas properties

     (8,128,323

Cash settlements on derivative financial instruments

  

Changes in operating assets and liabilities:

  

Accounts receivable

     (384,843

Other assets

     900   

Accounts payable and accrued liabilities

     1,365,006   
  

 

 

 

Net cash provided by operating activities

   $ 881,757   
  

 

 

 

Cash flows from investing activities:

  

Purchase of oil and gas properties and development expenditures

   $ (21,519,109

Proceeds from sale of oil and gas properties

     15,000,349   
  

 

 

 

Net cash used in investing activities

   $ (6,518,760
  

 

 

 

Cash flows from financing activities:

  

Capital contributions

     18,902,232   

Capital distributions

     (11,500,000

Parent company net investment

     833,275   
  

 

 

 

Net cash provided by financing activities

   $ 8,235,507   
  

 

 

 

Net increase in cash

   $ 2,598,504   

Cash — Beginning of period

   $ 454,669   
  

 

 

 

Cash — End of period

   $ 3,053,173   
  

 

 

 

Non—cash transactions:

  

Contributed Property

   $ 421,571   

Deferred financing costs

   $ 5,643   

The accompanying notes are an integral part of these financial statements.

 

7


Double Eagle Energy Permian LLC

Notes to the Financial Statements

 

1. ORGANIZATION AND NATURE OF BUSINESS

Description of the business and formation

Double Eagle Energy Permian LLC’s (the “Company,” “DEEP,” “we,” “our,” “us”), a Delaware limited liability company, was formed on September 29, 2016 (date of inception) through the conveyance of a predecessor entity, a wholly-owned subsidiary of Double Eagle Energy Operating II LLC, and additional contributed capital. See further discussion on formation and conveyance of the Company in Note 3 – Conveyance of Entities under Common Control . The Company’s principal business is crude oil and natural gas exploration, development and production with operations in the Midland Basin of West Texas in the United States. We are an independent energy company engaged in the acquisition, exploration, development and production of crude oil and natural gas properties. Currently, our strategy is to be an operator in the Midland Basin with a focus on horizontal drilling. However, for the year ended December 31, 2014, our strategy was to participate in non-operated working interests in wells and drilling projects within designated areas of operation through the acquisition of leasehold interests.

On September 29, 2016, the Company was formed by contributions from Double Eagle Energy Holdco LLC (“DEEH”), a newly formed parent of Double Eagle Energy Operating II LLC (the “Parent,” “DE”), of its wholly-owned subsidiary, Double Eagle Lone Star LLC (“Lone Star”) and a third party, Veritas Energy Partners Holdings, LLC (“Veritas”), of its wholly owned subsidiary, Veritas Energy Partners, LLC (“Veritas Sub”). DEEH and DE are also wholly owned subsidiaries of Double Eagle Energy Holdings II LLC (“DEEH II”), where all the board decisions and assets relating to Lone Star were historically managed.

Following the contribution of assets, DEEH held approximately 70% of DEEP’s equity, with Veritas holding the remaining 30%. The transactions between DEEH, DE, Lone Star and DEEH II were treated as a reorganization of entities under common control (as defined by U.S. GAAP), while Veritas’ contribution was treated as an acquisition of Veritas by DEEP. The financial statements included herein and associated notes and operations reflect the change in reporting entity and therefore are presented as if the Company existed and owned the assets since their acquisitions by the Parent. Lone Star was conveyed and recorded by the Company at DE’s respective historical carrying amounts. Certain amounts recorded and presented by the Parent that had not previously been allocated to the Company have been allocated to the Company to fairly present the financial results of the Company on a standalone basis. These allocations were performed utilizing systematic methods based on the operations of Lone Star, as explained below.

For the year ended December 31, 2014, the balance sheet includes all specific oil and gas assets, current assets, current liabilities and asset retirement obligations of Lone Star, and those assets that were specifically tracked within the entity. In addition to the specific assets of Lone Star, management allocated income statement and balance sheet items accounted for, by the Parent. These allocations were based on a ratio of oil and gas assets at Lone Star to the total oil and gas assets of the Parent. Management deemed this allocation method appropriate given the capital intensive nature of its business, and the correlation of the capital expenditures to the reserve-based borrowing facility. Accounts payable balances held by the Parent specifically associated with the Company, related to general and administrative expenses as noted below, were allocated from the Parent based on specific identification of payables related to the Company.

The statement of operations for the year ended December 31, 2014 also includes allocations for certain general and administrative expenses incurred by the Parent on behalf of the Company. The allocation method selected by management was based on the ratio of oil and gas assets held by Lone Star to the total oil and gas of the Parent; DEEP’s allocation based on oil and gas assets was 54.78%. No revenue was allocated to the Company, from the Parent or otherwise. All other costs and expenses were tracked at the individual asset level, and no allocations were necessary.

 

8


2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation – The accompanying financial statements and related notes present the balance sheet as of December 31, 2014, and the statement of operations, changes in members’ equity and cash flows for the year ended December 31, 2014. All intracompany transactions occurring between the Company and related entities have been eliminated. Certain transactions between the Company and DEEH, as well as DE, together referred to collectively as the Parent, have been included in these financial statement and are considered to be effectively settled at the time each transaction is recorded. The total net effect of the settlement of these transactions is reflected in the statement of members’ equity and Parent company net investment as net transfers (to)/from Parent, in the statement of cash flows as a financing activity and in the Company’s balance sheet as Parent company net investment. Unless otherwise stated, all amounts contained within the financial statement and accompanying notes are the responsibility of the Company, either as they were incurred by the Company through normal operations or were allocated to the Company from the Parent. As discussed in Note 3 – Conveyance of Entities under Common Control, the operations of the predecessor entity have been included from January 1, 2014.

The accompanying financial statements were prepared in accordance with U.S. generally accepted accounting principles (“GAAP”). Our financial statements include the accounts of the Company.

The Company’s financial statements include allocations of certain historically incurred amounts at DEEH and DE, including equity-based compensation and other general and administrative expenses incurred by the Parent on behalf of its wholly owned subsidiaries, of which the Company is included.

Use of Estimates – The preparation of financial statements under GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Estimates and judgments are based on information available at the time such estimates and judgments are made. Although management believes the estimates are appropriate, actual results may differ from those estimates.

The most significant estimates pertain to proved oil and natural gas reserves and related cash flow estimates used in impairment tests of long-lived assets, estimates of future development, dismantlement and abandonment costs, estimates relating to certain oil and natural gas revenues and expenses and estimates of expenses related to legal, environmental and other contingencies. Certain of these estimates require assumptions regarding future commodity prices, future costs and expenses and future production rates. Actual results could differ from those estimates.

Estimates of oil and natural gas reserves and their values, future production rates and future costs and expenses are inherently uncertain for numerous reasons, including many factors beyond the Company’s control. Reservoir engineering is a subjective process of estimating underground accumulations of 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 data available and of engineering and geological interpretation and judgment. In addition, estimates of reserves may be revised based on actual production, results of subsequent exploration and development activities, prevailing commodity prices, operating costs and other factors. These revisions may be material and could materially affect future depreciation, depletion and amortization (“DD&A”) expense, abandonment costs, and impairment expense.

Cash and Cash Equivalents – As of December 31, 2014, we consider all highly liquid investments with a remaining maturity of three months or less at the time of purchase to be cash or cash equivalents. Cash equivalents consist of cash in a short-term money market account.

Accounts Receivable – Accounts receivable are carried on a gross basis, with no discounting. The Company regularly reviews all aged accounts receivable for collectability and establishes an allowance as necessary for individual customer balances. As the Company has not experienced any credit losses, no allowance for doubtful accounts was recorded as of December 31, 2014.

 

9


Advances to Operators – The Company participates in the drilling of crude oil and natural gas wells with other working interest partners. Currently, the majority of the wells in which the Company participates are operated by unrelated third parties. Due to the capital intensive nature of crude oil and natural gas drilling activities, the operator of the well may request advance payments from other working interest partners for their share of the costs. The Company expects such advances to be applied by the operator against future development costs.

Oil and gas properties – The Company utilizes the successful efforts method of accounting for its oil and gas properties. Under this method, costs of acquiring properties, costs of drilling successful exploration wells, and development costs are capitalized. The costs of exploratory wells are initially capitalized pending a determination of whether proved reserves have been found. At the completion of drilling activities, the costs of exploratory wells remain capitalized if determination is made that proved reserves have been found. If no proved reserves have been found, the costs of each of the related exploratory wells are charged to expense. In some cases, a determination of proved reserves cannot be made at the completion of drilling, requiring additional testing and evaluation of the wells. The costs of such exploratory wells are expensed if a determination of proved reserves has not been made within a twelve-month period after drilling is complete. Exploration costs such as geological, geophysical, and seismic costs are expensed as incurred.

The capitalized costs of proved properties are depleted using the unit-of-production method based on proved developed or total proved reserves, as applicable. Costs of significant nonproducing properties, wells in the process of being drilled and development projects are excluded from depletion until the related project is completed and proved reserves are established or, if unsuccessful, impairment is determined.

Proceeds from the sales of individual properties and the capitalized costs of individual properties sold or abandoned are credited to the net book value of the amortization group, if doing so does not materially impact the depletion rate of an amortization base. Generally, no gain or loss is recognized until an entire amortization base is sold. However, gain or loss is recognized from the sale of less than an entire amortization base if the disposition is significant enough to materially impact the depletion rate of the remaining properties in the amortization base.

The Company performs assessments of its long-lived assets to be held and used, including proved oil and gas properties accounted for under the successful efforts method of accounting, whenever events or circumstances indicate that the carrying value of those assets may not be recoverable. An impairment loss is indicated if the sum of the expected future cash flows is less than the carrying amount of the assets. In these circumstances, the Company recognizes an impairment loss for the amount by which the carrying amount of the assets exceeds the estimated fair value of the assets. Estimating future cash flows involves the use of judgments, including estimation of the proved and unproved oil and gas reserve quantities, timing of development and production, expected future commodity prices, capital expenditures and production costs. We consider the inputs utilized in determining the fair value related to the impairment of long-lives assets to be Level 3 measurements in the fair value hierarchy. Since 2014, the Company has not realized any impairments of its proved properties.

Unproved oil and gas properties are periodically assessed for impairment on a project-by-project basis. These impairment assessments are affected by the results of exploration activities, commodity price outlooks, planned future sales or expirations of all or a portion of such projects. If the estimated future net cash flows attributable to such projects are not expected to be sufficient to fully recover the costs invested in each project, the Company will recognize an impairment loss at that time. As of December 31, 2014, the Company had not realized any impairments of its unproved property. However, for the year ended December 31, 2014, the Company recognized approximately $346,000, related to costs for a prospect area that was abandoned without acquiring any oil and gas properties, which are included in abandonment and dry hole costs on the statement of operations.

The Company capitalizes interest on expenditures for significant exploration and development projects that last more than six months while activities are in progress to bring the assets to their intended use. For the year ended December 31, 2014, the Company has not capitalized any interest as projects generally lasted less than six months.

Asset Retirement Obligations – Asset retirement obligations relate to future costs associated with the plugging and abandonment of crude oil and natural gas wells, removal of equipment and facilities from leased acreage and returning the land to its original condition. Estimates are based on estimated remaining lives of those wells based on reserve estimates, external estimates to plug and abandon the wells in the future, inflation, credit adjusted discount rates and federal and state regulatory requirements. We record the fair value of a liability for an asset retirement

 

10


obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. The liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Accretion expense is included in “Depreciation, depletion and amortization” on our statements of operations.

The estimated fair value of the Company’s asset retirement obligations at inception is determined by utilizing the income approach by applying a credit-adjusted risk-free rate, which takes into account the Company’s credit risk, the time value of money, and the current economic state, to the undiscounted expected abandonment cash flows. Given the unobservable nature of the inputs, the measurement of the asset retirement obligations was classified as Level 3 in the fair value hierarchy.

Deferred Financing Costs – Deferred financing costs include origination, legal and other fees to obtain or issue debt. These costs are deferred and reported on the balance sheet at cost, net of amortization. Total deferred financing costs are amortized on a straight line basis, which approximates the effective interest method, to interest expense over the term of the associated debt. The Company did not have any outstanding debt at the end of 2014.

Revenue Recognition – The Company recognizes crude oil, natural gas and natural gas liquids (“NGLs”) revenues from its interests in producing wells when production is delivered to, and title has transferred to, the purchaser and to the extent the selling price is reasonably determinable. The Company uses the sales method of accounting for natural gas balancing of natural gas production and would recognize a liability if the existing proven reserves were not adequate to cover the current imbalance situation. As of December 31, 2014, the Company’s natural gas production was in balance, meaning its cumulative portion of natural gas production taken and sold from wells in which it has an interest was materially consistent with its entitled interests in natural gas production from wells.

Concentrations of Credit Risk – As of December 31, 2014, the Company’s primary market consists of operations in the Midland Basin of West Texas in the United States. The Company has concentration of oil and gas production revenues and receivables due from the operators of wells in which we hold non-operated working interests. Our exposure to non-payment or non-performance by the operators, our customers and counterparties presents a credit risk. Generally, non-payment or nonperformance results from a customer’s or counterparty’s inability to satisfy obligations. We monitor the creditworthiness of our customers and counterparties and established credit limits according to our credit policies and guidelines, but cannot assure that any losses will be consistent with our expectations.

Furthermore, the concentration of our customers in the energy industry may impact our overall exposure to credit risk as customers may be similarly affected by prolonged changes in economic and industry conditions. The Company actively pursues to invest in non-operated wells with financially stable and experienced operators in the respective areas of exploration, development and production.

For the year ended December 31, 2014, the following third-party operators of properties the Company has interest in accounted for a significant portion of total revenue:

 

     For the Year Ended
December 31, 2014
 
     Oil & Gas Revenues  

CrownQuest Operating, LLC

     54.5

Brigham Resources Operating, LLC

     41.2
  

 

 

 
     95.7
  

 

 

 

Equity-Based Compensation – Prior to the formation and inception of DEEP, the Parent had issued its own Series B Units (the “Parent Incentive Units”) to certain employees of the Parent. The expense associated with the Parent Incentive Unit’s recorded at the Parent has been allocated to the Company and included in general and administrative expense in the accompanying statement of operations. See further discussion regarding the Parent’s B Units and the allocated $82,000 of expense in Note 5 – Member’s Equity and Equity-Based Compensation .

Fair Value Hierarchy – Fair value represents the price that would be received to sell the asset or paid to transfer the liability in an orderly transaction between market participants at the reporting date. The Company’s assets and

 

11


liabilities that are measured at fair value at each reporting date are classified according to a hierarchy that prioritizes inputs and assumptions underlying the valuation techniques. This fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities and the lowest priority to unobservable inputs, and consists of three broad levels:

 

    Level 1—Assets and liabilities recorded at fair value for which values are based on unadjusted quoted prices for identical assets or liabilities in an active market that management has the ability to access. Active markets are considered to be those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

 

    Level 2—Assets and liabilities recorded at fair value for which values are based on quoted prices in markets that are not active or model inputs that are observable either directly or indirectly for substantially the full term of the asset or liability. Substantially all of these inputs are observable in the marketplace throughout the full term of the price risk management instrument and can be derived from observable data or supported by observable levels at which transactions are executed in the marketplace.

 

    Level 3—Assets and liabilities recorded at fair value for which values are based on prices or valuation techniques that require inputs that are both unobservable and significant to the overall fair value measurement. Unobservable inputs that are not corroborated by market data. These inputs generally reflect management’s own assumptions about the assumptions a market participant would use in pricing the asset or liability.

Valuation techniques that maximize the use of observable inputs are favored. Assets and liabilities are classified in their entirety based on the lowest priority level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the fair value hierarchy.

Recently Issued Accounting Standards

Leases . In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-02, Leases (Topic 842), which revises the accounting for leases by requiring certain leases to be recognized as assets and liabilities in the balance sheet, and requiring companies to disclose additional information about their leasing arrangements. We expect to adopt the provisions of this standard effective January 1, 2019. The Company is currently evaluating the new guidance and has not determined the impact, if any, this standard may have on our financial statements.

Revenue recognition . In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). The objective of ASU 2014-09 is greater consistency and comparability across industries by using a five-step model to recognize revenue from customer contracts. ASU 2014-09 also contains some new disclosure requirements under GAAP. In August 2014, the FASB issued Accounting Standards Update No. 2014-14, Deferral of the Effective Date (“ASU 2014-14”). ASU 2014-14 defers the effective date of the new revenue standard by one year, making it effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. In 2016, the FASB issued additional accounting standards updates to clarify the implementation guidance of ASU 2014-09. The Company is currently evaluating the method of adoption as well as the effect that adopting this guidance will have on its financial position, cash flows and results of operations.

Going concern . In August 2014, the FASB issued Accounting Standards Update No. 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (“ASU 2014-15”). ASU 2014-15 codifies in GAAP management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern and to provide related footnote disclosures. ASU 2014-15 is effective for the annual reporting period ending after December 15, 2016 and for annual periods and interim periods thereafter. The Company adopted this guidance in fiscal year 2016.

Income Taxes . In November 2014, FASB issued ASU 2014-17, Income Taxes (“ASU 2014-17”). ASU 2014-17 simplifies the presentation of deferred income taxes and requires deferred tax assets and liabilities be classified as noncurrent in the balance sheet. The amendments in this ASU are effective for fiscal years beginning after

 

12


December 15, 2016, and interim periods within those fiscal years, and early adoption is permitted. Entities can transition to the standard either retrospectively to each period presented or prospectively. As the Company is only subject to the Texas Margin Tax, as discussed in Note 7 – Income Taxes , the Company is currently evaluating the new guidance and has not determined the impact, if any, this standard may have on our financial statements.

Imputation of Interest . In April 2014, FASB issued ASU 2014-03, Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs (“ASU 2014-03”). ASU 2014-03 requires debt issuance costs related to a recognized debt liability to be presented as a direct reduction of the carrying amount of that debt in the balance sheet, consistent with the presentation of debt discounts. The amendments in this ASU are effective for fiscal years beginning after December 15, 2014, and interim periods within those fiscal years, and early adoption is permitted. Entities will be required to apply the guidance on a retrospective basis to each period presented as a change in accounting principle. In August 2014, the FASB issued ASU 2014-15, Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs (“ASU 2014-15”) which amends ASU 2014-03 to clarify the presentation and subsequent measurement of debt issuance costs associated with line of credit arrangements, such that entities may continue to apply current practice. The Company adopted this guidance in fiscal year 2016.

 

3. CONVEYANCE OF ENTITIES UNDER COMMON CONTROL

On November 12, 2014, the Parent was formed pursuant to a Master Reorganization Agreement whereas certain subsidiaries, including a predecessor entity which formed the Company, from Double Eagle Holdings, which is also owned by the private equity financial sponsor (the “PE Sponsor”) and the certain members of the Company’s management (“Management Group”), were conveyed to the Parent. In exchange for the subsidiaries conveyed, Series A Units of the Parent were issued to the PE Sponsor, the Management Group and other employees which had profit interests in Double Energy Holdings.

In addition to the subsidiaries conveyed, capital contributions from the PE Sponsor and the Management Group were contributed at inception to form the Parent. The conveyance constituted a transaction between entities under common control (as defined by GAAP), whereas the operations of a predecessor entity are presented as if the Company existed and owned the assets since their initial acquisition. The assets and obligations were conveyed and recorded by the Company at the predecessor entity’s respective carrying amounts.

 

4. ASSET RETIREMENT OBLIGATIONS

The carrying amount of the Company’s ARO on the Company’s balance sheet at December 31, 2014 was approximately $6,800. At the inception of drilling activities, the Company determines the ARO by calculating the present value of estimated future cash flows related to the liability if a reasonable estimate of fair value can be made and the corresponding cost is capitalized as part of the carrying amount of the related long-lived asset. Estimating the future ARO requires management to make estimates and judgments regarding the timing and existence of a liability, as well as what constitutes adequate restoration when considering current regulatory requirements. Inherent in the fair value calculation are numerous assumptions and judgments, including the ultimate costs, inflation factors, credit adjusted discount rates, timing of settlement and changes in the legal, regulatory, environmental and political environments. These assumptions represent Level 3 inputs. To the extent future revisions to these assumptions impact the fair value of the existing ARO liability, a corresponding adjustment is made to the related asset.

The following table provides a reconciliation of the changes in the asset retirement obligations generally associated with future costs associated with the plugging and abandonment of crude oil and natural gas wells, removal of equipment and facilities from leased acreage and returning the land to its original condition for the period indicated:

 

     For the Year Ended
December 31, 2014
 

Beginning asset retirement obligations

   $ —     

Liability incurred

     6,789   

Revisions in estimates

     —     

Acquisitions

     —     

Accretion expense

     —     
  

 

 

 

Ending asset retirement obligations

   $ 6,789   
  

 

 

 

 

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As of December 31, 2014, no assets are legally restricted for use in settling asset retirement obligations, and all obligations are classified as long-term in the balance sheet as we do not expect to incur any of these charges within the next year.

 

5. MEMBERS’ EQUITY AND EQUITY-BASED COMPENSATION

On November 12, 2014, the Parent entered into a limited liability company agreement (“LLC Agreement”) with its Management Group and the PE Sponsor with an initial capital commitment of $165.0 million. The Parent was formed with a conveyance of subsidiaries from Double Eagle Holdings and cash contributions from the PE Sponsor and the Management Group. Certain employees of Double Eagle Holdings (“Other Management Members”) who held profit interests were distributed Series A Units in the Parent which constituted their respective distributed value of the assets transferred. The Other Management Members that obtained Series A Units in the Parent through their profit interest in Double Eagle Holdings will not participate in future contributions.

As of December 31, 2014, the PE Sponsor and the Management Group have contributed $33.0 million to the Parent for Permian asset operations. As of December 31, 2014, DEEO II had remaining capital commitments of $132.0 million from the PE Sponsor and the Management Group.

Prior to the formation and inception of DEEP on September 29, 2016, the Parent had issued Series B Units (the “Parent Incentive Units”) to certain employees of the Parent. As of December 31, 2014, the Parent had issued 875 Series B Units of which 859 were unvested. The weighted average grant date fair value per Series B Unit is $10,300. These Parent Incentive Units are tied to certain performance metrics and return hurdles of the Parent and its wholly owned subsidiaries including, but not limited to, DEEP. Eighty percent of the Parent Incentive Units vest monthly over a four-year period, with the remaining twenty percent only vesting upon a liquidity event, as defined in the Parent’s Limited Liability Company Agreement. The Parent accounts for these units as equity awards in accordance with ASC 718 and records expense related to these awards based on the grant date fair value of the awards. These units are unrelated to the ownership of DEEP. The financial obligation or payout requirements of the Parent Incentive Units belongs to the Parent.

As the employees who were awarded Parent Incentive Units provided services to the assets associated with the Company during 2014, a portion of the cost associated with the Parent Incentive Units has been allocated to the Company, as discussed below.

For the year ending December 31, 2014, approximately $82,000 of the expense associated with the Parent Incentive Unit’s recorded at the Parent has been allocated to the Company and included in general and administrative expense in the accompanying statement of operations. The expense was allocated during the year based on the allocation of total capitalized oil and gas properties between Lone Star and Rockies at the end of the year. This methodology is consistent with the treatment of other statement of operation items from the Parent that were identified to be allocated to the Company for standalone presentation. The offset to the allocated expense will be included in Parent Company Net Investment, a members’ equity account of the Parent reflecting their invested balance in the Company.

 

6. FAIR VALUE MEASUREMENT

In accordance with the FASB’s authoritative guidance on fair value measurements, the Company’s financial assets and liabilities are measured at fair value on a recurring basis. The book value of the Company’s current assets and liabilities approximate their fair value due to the short-term nature of the instruments. The Company recognizes its non-financial assets and liabilities, such as ARO and proved oil and natural gas properties upon impairment, at fair value on a non-recurring basis. See Note 4 – Asset Retirement Obligations for further discussion.

 

7. INCOME TAXES

Income Taxes – The Company is not subject to federal or state income taxes, except as noted below, as we are organized as a partnership for income tax purposes and the results of operations are taxable directly to the members. Accordingly, each member is responsible for its share of federal and state income tax.

 

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Texas Margin Tax – The Company is subject to the Texas Margin Tax that requires tax payments at a maximum statutory effective rate of 0.75% on the taxable margin of each taxable entity that does business in Texas. The margin tax qualifies as an income tax under Accounting Standards Codification 740, Income Taxes (FAS 109/FIN 48) (“ASC 740”), which requires us to recognize currently the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis attributable to such tax. For the year ended December 31, 2014, the Company has a greater apportionment rate in Texas as well as greater temporary differences between GAAP and taxable income. As such, as of December 31, 2014, the Company recognized a deferred tax liability in the amount of approximately $58,000 related to the Texas Margin Tax which is included in the accompanying balance sheet.

Uncertain Tax Positions – We evaluate the uncertainty in tax positions taken or expected to be taken in the course of preparing our financial statements to determine whether the tax positions are more likely than not of being sustained by the applicable tax authority. Tax positions with respect to tax at the partnership level deemed not to meet the more likely than not threshold would be recorded as a tax benefit or expense in the current year. We believe that there are no uncertain tax positions that would impact our operations for the year ended December 31, 2014, and that no provision for income tax is required for these financial statements. However, our conclusions regarding the evaluation are subject to review and may change based on factors including, but not limited to, ongoing analyses of tax laws, regulations and interpretations thereof. With all tax positions meeting the “more likely than not” threshold under ASC 740, the Company determined that there is no current effect on the financial statements from a lapse of the statute of limitations as it relates to unrecognized tax benefits. Additionally, the Company’s tax years 2013 and 2014 remain open for examination. As of December 31, 2014, the Company has no amounts related to accrued interest and penalties.

 

8. RELATED PARTY TRANSACTIONS

The PE Sponsor, a leading global alternative investment manager, has a substantial equity investment in us and has three individuals on our Board of Directors, when formed on September 29, 2016. The PE Sponsor’s investment in and relationship with us qualifies them as a related party. The Parent of the Company is party to several agreements with the PE Sponsor.

Transaction Fee

The Parent is party to a Transaction Fee Agreement, dated November 12, 2014 with an affiliate of the PE Sponsor which requires us to pay 1% of the total equity contributed to DEEO II by the PE Sponsor pursuant to a merger or acquisition of equity or assets if such contribution by the PE Sponsor is $25.0 million or greater (“Transaction Fee”). For the year ended December 31, 2014, Parent did not incur any Transaction Fees.

Services Agreement

The Parent is party to an consulting and advisory services agreement(“Services Agreement”) which requires us to compensate the PE Sponsor equal to the greater of (i) 1% of earnings before interest, income taxes, depletion, depreciation, amortization and exploration expense per quarter, and (ii) approximately $34,250 per quarter (the “Consulting Fee”). The Services Agreement also provides for reimbursement to the PE Sponsor for any reasonable out-of-pocket. As of December 31, 2015, approximately $18,700 was allocated to the Company and included in accounts payable to related parties in the accompanying balance sheet. The Consulting Fee to the Company is pro-rated from November 12 to December 31, 2014 combined with the allocation percentage in Note 1 – Basis of Presentation .

Certain members of management and entities owned and controlled by those members of management have certain agreements with the Parent, whereas consideration is paid to those members or their controlled entities for services performed or use of commonly owned assets, as follows:

Shared Services Agreement

The Parent is party to an agreement with a management member’s entity whereas this entity provides certain general and administrative services to Double Eagle Energy Holdings II LLC (“Shared Services Agreement”) for a monthly fee of approximately $14,500 (“Shared Services Expense”). For the year ended December 31, 2014, the

 

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Parent incurred approximately $23,700 in Shared Services Expense, of which approximately $13,000 was allocated to the Company, which is included in general and administrative expense in the accompanying statement of income. As of December 31, 2014, no expenses related to the Shared Services Agreement were included in accounts payable to related parties in the accompanying balance sheet.

Management Services Agreement

For the year ended December 31, 2014, the Parent billed a total of $379,000 related to the services performed for the related affiliate, of which approximately $207,700 was allocated to the Company and included as an offset to general and administrative expense in the accompanying statement of income. As of December 31, 2014, $379,000 was included in accounts receivable by the Parent, of which approximately $207,700 was allocated to the Company and included as an offset to accounts payable to related parties in the accompanying balance sheet.

Acquisitions / Contributions of oil and gas properties

From time to time, the Company acquires oil and gas properties from other management members’ controlled entities. These transactions are based on the fair value of the assets that are purchased which supports an arms-length transaction between the Company and a related party. In certain instances, the Company reimburses service costs incurred that related to the acquisition of these assets. For the year ended December 31, 2014, the Company paid management members’ controlled entities approximately $547,000 for oil and gas properties and associated service costs.

In addition to cash purchases, management members have the ability to offset cash capital contributions with contributions of oil and gas properties. Other management members’ controlled entities have similar oil and gas operations in the Midland Basin and these entities have been in existence prior to the formation of the Company. During 2014, management identified certain assets that were directly accretive to the asset base of the Company, and thus contributed these properties alongside cash capital calls from the PE Sponsor. The value derived for the contributions were based on applicable comparable market transactions, at fair value, for similar assets in the Midland Basin. During 2014, approximately $422,000 in oil and gas properties were contributed to the Company in exchanged for equity interests.

 

9. COMMITMENTS AND CONTINGENCIES

From time-to-time we are party to certain legal litigation, regulatory or administrative proceedings that arise in the ordinary course and are incidental to our business. As of December 31, 2014, there are no such pending proceedings to which we are party to that our management believes will have a material adverse effect on our results of operations, cash flows or financial condition. However, future events or circumstances, currently unknown to management, will determine whether the resolution of any litigation or claims will ultimately have a material effect on our results of operations, cash flows or financial condition in any future reporting periods.

Casualties and Other Risks – The Company maintains coverage in various insurance programs, which provide us with property damage and other coverage which are customary for the nature and scope of our operations.

The Company believes we have adequate insurance coverage, although insurance will not cover every type of loss that might occur. As a result of insurance market conditions, premiums and deductibles for certain insurance policies could increase significantly, and in certain instances, insurance may become unavailable, or available at reduced coverage.

If we were to incur a significant loss for which we were not adequately insured, the loss could have a material impact on our results of operations, cash flow or financial condition. In addition, the proceeds of any available insurance may not be paid in a timely manner and may be insufficient if such an event were to occur. Any event that interrupts our revenues, or which causes us to make a significant expenditure not covered by insurance, could reduce our ability to meet future financial obligations.

Commitments – During 2014, the Company entered into an agreement whereas a certain oil and gas lease was assigned to the Company in exchange for five equal annual installment payments of $185,000 to the assignor of the lease. Each annual payment is due by January 15th of the respective year. The Company includes the short term portion of the liability in “Accounts payable and accrued liabilities” and the long term portion in “Deferred lease acquisition costs” in the accompanying balance sheet.

 

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            Payments Due by Period  
     Total      2015      2016      2017      2018      2019      Thereafter  

Deferred lease acquisition costs

     925,000         185,000         185,000         185,000         185,000         185,000         —     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total

   $ 925,000       $ 185,000       $ 185,000       $ 185,000       $ 185,000       $ 185,000       $ —     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

As of December 31, 2014, the Company had outstanding commitments related to deferred acquisition costs totaling $925,000.

 

10. DEFINED CONTRIBUTION PLAN

The Company participates in a 401(k) defined contribution plan sponsored by the Parent, for the benefit of all employees at their date of hire. The plan allows eligible employees to contribute a portion of their annual compensation, not to exceed annual limits established by the federal government. The Parent makes matching contribution of up to a certain percentage of an employee’s contributions. For the year ended December 31, 2014, the Company was allocated contributions to the plan of approximately $7,800 from the Parent.

 

11. SUBSEQUENT EVENTS

On January 1, 2015, employees of Double Eagle Operating became employed by the Parent. Due to this, the Company entered into a Service Agreement dated January 1, 2015 whereas our employees would provide employment services to Double Eagle Operating for a monthly fee of $15,000. This agreement was not extended and terminated automatically on the second anniversary, January 1, 2017.

On February 1, 2015, Double Eagle renewed their office lease with Double Eagle Offices, LLC, whereas Double Eagle leases office space for general business activity for a period of three years at a monthly rate of $13,200. Double Eagle Offices, LLC is owned and controlled by the Company’s Management Group. Due to the significant influence the Management Group has over both entities, the Company considers Double Eagle Offices, LLC a related party. Rental rates were determined based on comparable rates charged by third parties. The Company leases office buildings under operating leases.

On September 13, 2015, an Election Letter was executed pursuant to Section 5.02(g) of the LLC Agreement whereas the PE Sponsor exercised its right to increase its commitments to the Company through ANRP Double Eagle Holdings II, L.P., an affiliate of the PE Sponsor. The PE Sponsor’s commitment amount is $175.0 million to the Company. In addition on September 13, 2015, the Management Group executed an Election Letter pursuance to Section 5.02(g) of the LLC Agreement whereas the Management Group elected to increase their commitment to the Company in the amount of $39.4 million.

On September 15, 2015, the Company completed the acquisition of approximately 6,100 net acres of producing and non-producing leasehold properties for purchase price of $65.2 million, subject to customary purchase price adjustments. The Company accounted for the acquisition as a business combination in accordance with ASC 805. The transaction included $15.9 million in Proved – Producing reserves. At the time of the acquisition, the properties included 117 producing wells and two wells in development. The Company held non-significant non-operated working interest in the producing wells. The properties were located in Glasscock and Reagan County Texas in the Midland Basin. The Company also incurred $133,801 in asset retirement obligations related to this acquisition. Transaction costs of approximately $45,600 were recognized in “General and administrative” expenses in the accompanying statement of operations for the year ended December 31, 2015.

On April 21, 2016, the Company entered into a Membership Interest Purchase and Sale Agreement (“MIPSA”) with MCM Energy Partners, LLC (“MCM”), whereas the Company acquired eight-five percent (85%) of the membership interest of Novus Land Services, LLC (“Novus”). For the consideration for the sale, assignment, transfer and conveyance of the acquired interest, the Company paid MCM approximately $19.2 million in aggregate, representing 85% of the fair value of the assets and liabilities as of the closing date. The acquisition was concluded to be treated as a business combination per ASC 805, Business Combinations, under the acquisition method as noted in ASC 805-10-05-4. The assets and liabilities held by Novus, as well as the results of its operations will be

 

17


consolidated into the financial statements issued by the Company for all periods subsequent to the acquisition date. The acquisition is expected to comprise less than 5% of the future annual pre-tax income and net assets of the Company.

On February 3, 2017, the Company entered into another MIPSA whereas the Company purchased the remaining fifteen percent (15%) non-controlling interest in Novus Land Services, LLC. The Company paid consideration in the amount of $14.6 million for the 15% ownership. The acquisition will be subject to customary due diligence and post-closing matters.

On September 29, 2016, to align its business operations with management’s revised strategy to become an operator with a focus on horizontal drilling, the Parent entered into an LLC agreement whereas the Parent contributed all of the ownership interests in a wholly owned subsidiary (“Lone Star”) to the Company in exchange for Series A-1 units representing an approximate 70% interest in DEEP. Veritas Energy Partners Holdings, LLC (“Veritas”), a third party, contributed all of the ownership interests of its wholly owned subsidiary, Veritas Energy Partners, LLC (“Veritas Energy”) to DEEP in exchange for Series A-1 units representing an approximate 30% interest in DEEP (the “Veritas Acquisition”). Following the Veritas Acquisition, Veritas Energy ceased to exist as a standalone entity. The assets, liabilities and results of operations of Veritas Energy for the period ended December 31, 2015 are not included in, or otherwise consolidated with, the accompanying financial statements, nor described in the accompanying notes, contained herein. At closing, DEEP recorded the assets and liabilities of Veritas Energy at their respective fair values. The following table summarizes the fair values of assets acquired and liabilities assumed, as of September 29, 2016. The preliminary purchase price allocation is as follows:

 

Condensed Balance Sheet of Assets Acquired and Liabilities Assumed

 

Current assets

  

Cash and cash equivalents

   $ 6,777,181   

Accounts receivable

     2,674,057   

Other current assets

     154,656   
  

 

 

 

Total current assets

     9,605,894   

Oil and gas properties

  

Proved oil and gas properties

     38,941,679   

Unproved oil and gas properties

     277,722,754   
  

 

 

 

Total fair value of oil and gas properties acquired

     316,664,433   

Liabilities assumed

  

Accounts payable and accrued liabilities

     4,815,078   

Asset retirement obligation

     686,800   
  

 

 

 

Consideration transferred

   $ 320,768,449   
  

 

 

 

The final purchase price allocation is pending the completion of the valuation of the assets and liabilities contributed.

Prior to the Veritas Acquisition, for the period ended September 29, 2016, Veritas Energy generated approximated $700,000 in revenue, which resulted in a $2.5 million loss from operations for the period.

On September 30, 2016, in order to fund the Veritas Acquisition and execute on the Company’s revised business strategy, the Company entered into a credit agreement with JPMorgan Chase Bank, N.A. (“JPMorgan”), with a maximum revolving credit facility of $500.0 million with an initial borrowing base of $60.0 million (“JPM Revolver”). However, the Company’s ability to draw on the JPM Revolver is limited by an Indenture Agreement between the Company and Capital Provider, as discussed below, thereby effectively reducing the borrowing base. The JPM Revolver is secured by liens on substantially all of the Company’s properties and guarantees from the Company’s subsidiaries. The Credit Agreement of the JPM Revolver contains restrictive covenants that may limit our ability to, among other things, issue or incur additional indebtedness, enter into mergers, make investments or enter into hedging contracts. With the issuance of the JPM Revolver, the debt allocated to the Company under the Wells Fargo RBL, entered into by the Parent, was extinguished. The unamortized portion of the related deferred financing fees previously allocated to the company, approximately $187,000, were fully amortized on this date and included in the statement of operations.

Upon execution of the Credit Agreement, we were required to provide evidence satisfactory to the JPMorgan that we had entered into hedge agreements, as defined, covering at least 50% of reasonably anticipated production for each month through December 31, 2017. During the period which the Credit Agreement is in effect, hedged volumes may not exceed 85% of the reasonably anticipated production (based on forecasts from reserve reports acceptable to the Administrative Agent) for any 66 month period from the creation of the most recent Hedging Agreement. The Credit Agreement also specifies the hedge agreements may not be entered into for speculative purposes. Prior to this requirement, the Company had not participated in hedging activities.

 

18


On November 7, 2016, DEEP entered into a Unit Subscription Agreement (the “Subscription Agreement”), with funds affiliated with Capital Provider and related affiliates (“Capital Provider”), to sell units in DEEP, representing approximately 7.5% of DEEP’s equity interests, to Capital Provider for $150 million. The Company amended the LLC Agreement to provide for the issuance of Series C Units, to be awarded by and with the approval of the Board of Directors, to create a new class of Capital Interest Members of the Company. In connection with the equity issued pursuant to the Subscription Agreement, the Capital Provider affiliates are entitled to certain liquidation preferences in the event of a liquidity event or certain asset sales, as defined in the Subscription Agreement

In conjunction with the Unit Subscription Agreement with Capital Provider, 73,876,046 of Series C Units in DEEP, representing approximately 7.5% of DEEP’s equity interests, were sold to Capital Provider for $150 million. The Series C Units entitle holders to participate in the net profits of the Company; however, holders of Series C Units do not possess voting rights or the right to consent or approve any action or matter. In the event of a liquidation of the Company, Capital Provider’s Series C Units entitle them to a preferred return, contingent on presence of certain facts. Upon the closing of the Subscription Agreement, the equity interests in DEEP held by DEEH, Veritas and Capital Provider were approximately 64.75%, 27.75% and 7.5%, respectively.

In addition to the Company’s equity offering to Capital Provider, on November 7, 2016 DEEP and Capital Provider also entered into a Senior Notes Purchase Agreement whereby DEEP may issue and sell to Capital Provider up to $300.0 million in 8.75% senior unsecured notes, due in 2022 (the “Capital Provider Notes”). The Capital Provider Notes may be issued between November 7, 2016 and December 31, 2017 (the “Commitment Period”) in series of not less than $100.0 million per issue. Borrowings, pursuant to draw down requests as defined in the Senior Note Purchase Agreement, may not be less than $100.0 million and are subject to a 1% original issue discount (“OID”), and are limited by debt covenants and an Indenture Agreement also imposing restrictions on the Company’s ability to borrow additional debt. The Capital Provider Notes are also subject to a contingent commitment fee, payable in cash, equal to the lesser of $12 million or 4.00% of any of the unfunded $300.0 million commitment that is not issued by the end of the Commitment Period. As of February 4, 2017, no amounts were drawn on the Capital Provider Notes, however no contingency was recognized for the Capital Provider Notes contingency, as the probability of incurring the cost could not be determined by Management.

We have evaluated subsequent events through February 4, 2017, the date the financial statements were available to be issued.

 

19


DOUBLE EAGLE ENERGY PERMIAN LLC

Supplemental Information

(Unaudited)

 

12. SUPPLEMENTAL OIL AND GAS RESERVE INFORMATION – UNAUDITED

The reserve estimates at December 31, 2014 presented in the tables below are based on reports prepared by Cawley, Gillespie & Associates, Inc., the Company’s independent reserve engineers, in accordance with the SEC rules on oil and gas reserve estimation and disclosures. In accordance with SEC requirements, the pricing used by the Company is based on the 12-month unweighted arithmetic average of the first-day-of-the-month spot price for the period January through December and adjusted by lease for quality, transportation, geographical differentials, marketing bonuses or deductions and other factors affecting the price received at the wellhead. The use of SEC pricing rules may not be indicative of actual prices realized by the Company in the future. The commodity prices, based on SEC pricing and inclusive of adjustments for quality and location used in determining future net revenues related to the standardized measure calculation, are as follows:

 

     As of
December 31, 2014
 

Oil (NYMEX price per Bbl)

   $ 84.29   

Natural Gas (Henry Hub price per Mcf)

   $ 3.62   

Natural Gas Liquids (per Engineering report per Bbl)

   $ 26.25   

During 2014, all of the Company’s oil and natural gas producing activities were conducted within the state of Texas.

Oil and natural gas reserve quantity estimates are subject to numerous uncertainties inherent in the estimation of quantities of proved reserves, the projection of future production rates and the timing of future development expenditures. The Company emphasizes that reserve estimates are inherently imprecise and that estimates of new discoveries and undeveloped locations are more imprecise than estimates of established proved producing oil and natural gas properties. Accordingly, these estimates are expected to change as future information becomes available.

Proved oil and natural gas reserves are the estimated quantities of oil and natural gas that geological and engineering data demonstrate, with reasonable certainty, to be recoverable in future years from known reservoirs under economic and operating conditions (i.e., prices and costs) existing at the time the estimate is made. Proved developed oil and natural gas reserves are proved reserves that can be expected to be recovered through existing wells and equipment in place and under operating methods being utilized at the time the estimates were made.

Estimated Quantities of Proved Oil and Natural Gas Reserves

The following table sets forth the Company’s estimated net proved, proved developed and proved undeveloped reserves at December 31, 2014:

 

     Oil
(MBbl)
     Gas
(MMcf)
     NGL
(MBbl)
     Mboe  

Total Proved Reserves

           

Balance, beginning of period

     —           —           —           —     

Revisions of previous estimates

     —           —           —           —     

Extensions, discoveries and other additions

     339.9         686.7         143.9         598.3   

Purchase of reserves in place

     —           —           —           —     

Production

     (14.3      (18.4      (3.7      (21.1

Sales of reserves in place

     —           —           —           —     
  

 

 

    

 

 

    

 

 

    

 

 

 

Net proved reserves in place at December 31, 2014

     325.6         668.3         140.2         577.2   
  

 

 

    

 

 

    

 

 

    

 

 

 

Proved developed reserves, December 31, 2014

     98.7         181.5         39.0         168.0   
  

 

 

    

 

 

    

 

 

    

 

 

 

Proved undeveloped reserves, December 31, 2014

     226.9         486.8         101.2         409.2   
  

 

 

    

 

 

    

 

 

    

 

 

 

 

20


Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Natural Gas Reserves

The Standardized Measure of Discounted Future Net Cash Flows and Changes Therein Relating to Proved Oil and Natural Gas Reserves (“Standardized Measure”) does not purport to present the fair market value of our oil and natural gas properties. An estimate of such value should consider, among other factors, anticipated future prices of oil and natural gas, the probability of recoveries in excess of existing proved reserves, the value of probable reserves and acreage prospects, and perhaps different discount rates. It should be noted that estimates of reserve quantities, especially from new discoveries, are inherently imprecise and subject to substantial revision.

The Company’s estimated net proved reserves and related future net revenues and Standardized Measure were determined using index prices for oil and natural gas, which are held constant throughout the life of the properties. Future operating costs, production taxes and development costs were based on current costs as of each year-end.

The following table sets forth the Standardized Measure of discounted future net cash flows from projected production of the Company’s estimated net proved oil and natural gas reserves:

 

     As of
December 31, 2014
 

Future cash inflows

   $ 33,547,567   

Future production costs

     (5,730,827

Future development costs

     (5,583,219

Future income tax expense

     (117,980
  

 

 

 

Future net cash flows

   $ 22,115,541   

10% annual discount for estimated timing of cash flows

     (13,404,781
  

 

 

 

Standardized measure of discounted future net cash flows

   $ 8,710,760   
  

 

 

 

Future net cash flows do not include the effects of U.S. federal income taxes on future results because the Company is a limited liability company not subject to entity-level federal income taxes. Accordingly, no provision for federal corporate income taxes has been provided because taxable income was passed through to the Company’s equity holders. However, the Company’s operations are located in Texas are subject to an entity-level tax, the Texas Margin Tax, at a statutory rate of up to 0.75% of income that is apportioned to Texas.

The following table sets forth the changes in the Standardized Measure of discounted future net cash flows applicable to estimated net proved reserves for the periods presented:

 

     As of
December 31, 2014
 

Balance, beginning of period

   $ —     

Sales of oil and natural gas produced during the period, net

     (1,153,098

Net changes in prices and production costs

     —     

Net changes in future development costs

     —     

Net changes due to extensions & discoveries

     9,915,572   

Net changes due to revisions of previous quantity estimates

     —     

Purchases of reserves in place

     —     

Sale of reserves in place

     —     

Accretion of discount

     —     

Changes in timing and other

     —     

Net change in income taxes

     (51,714
  

 

 

 

Standardized measure of discounted future net cash flows

   $ 8,710,760   
  

 

 

 

 

21

Exhibit 99.5

 

LOGO

Financial Statements

As of December 31, 2015

and For the Year Then Ended


DOUBLE EAGLE ENERGY PERMIAN LLC

INDEX TO THE FINANCIAL STATEMENTS

 

     Page  

Report of Independent Auditors

     3   

Balance Sheet at December 31, 2015

     4   

Statement of Operations For the Year Ended December 31, 2015

     5   

Statement of Changes in Members’ Equity For the Year Ended December 31, 2015

     6   

Statement of Cash Flows For the Year Ended December 31, 2015

     7   

Notes to the Financial Statements

     8   

Supplemental Information

     22   

 

2


LOGO

Report of Independent Auditors

The Board of Directors

Double Eagle Energy Permian LLC

We have audited the accompanying financial statements of Double Eagle Energy Permian LLC, which comprise the balance sheet as of December 31, 2015, and the related statements of operations, changes in members’ equity, and cash flows for the year then ended, and the related notes to the financial statements.

Management’s Responsibility for the Financial Statements

Management is responsible for the preparation and fair presentation of these financial statements in conformity with U.S. generally accepted accounting principles; this includes the design, implementation, and maintenance of internal control relevant to the preparation and fair presentation of financial statements that are free of material misstatement, whether due to fraud or error.

Auditor’s Responsibility

Our responsibility is to express an opinion on these financial statements based on our audit. We conducted our audit in accordance with auditing standards generally accepted in the United States. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement.

An audit involves performing procedures to obtain audit evidence about the amounts and disclosures in the financial statements. The procedures selected depend on the auditor’s judgment, including the assessment of the risks of material misstatement of the financial statements, whether due to fraud or error. In making those risk assessments, the auditor considers internal control relevant to the entity’s preparation and fair presentation of the financial statements in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the entity’s internal control. Accordingly, we express no such opinion. An audit also includes evaluating the appropriateness of accounting policies used and the reasonableness of significant accounting estimates made by management, as well as evaluating the overall presentation of the financial statements.

We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion.

Opinion

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Double Eagle Energy Permian LLC at December 31, 2015, and the results of its operations and its cash flows for the year then ended December 31, 2015 in conformity with U.S. generally accepted accounting principles.

Change in Reporting Entity

As discussed in Note 1 to the financial statements, the 2015 financial statements reflect retrospective application for the change in reporting entity. Our opinion is not modified with respect to this matter.

 

LOGO

February 4, 2017

 

 

 

3


Double Eagle Energy Permian LLC

Balance Sheet

at December 31, 2015

 

Assets

  

Current assets:

  

Cash and cash equivalents

   $ —     

Accounts receivable

     5,157,409   

Advances to operators

     89,521   
  

 

 

 

Total current assets

     5,246,930   

Property and equipment:

  

Oil and gas properties, successful efforts method of accounting:

  

Proved properties

     86,448,623   

Unproved properties

     172,802,546   
  

 

 

 

Total oil and gas properties

     259,251,169   

Less: Accumulated depreciation, depletion and amortization

     (4,585,421
  

 

 

 

Total oil and gas properties, net

     254,665,748   

Deferred financing fees, net

     131,968   
  

 

 

 

Total assets

   $ 260,044,646   
  

 

 

 

Liabilities and Members’ Equity

  

Current liabilities:

  

Accounts payable and accrued liabilities

   $ 2,069,861   

Accounts payable to related parties

     1,977,282   

Accrued oil and gas development expenditures

     9,268,729   
  

 

 

 

Total current liabilities

     13,315,872   

Texas margin tax

     300,353   

Deferred lease acquisition costs

     555,000   

Long-term debt

     16,200,000   

Asset retirement obligations

     1,055,482   

Commitments and contingencies

     —     

Members’ equity

     228,617,939   
  

 

 

 

Total liabilities and members’ equity

   $ 260,044,646   
  

 

 

 

The accompanying notes are an integral part of these financial statements.

 

4


Double Eagle Energy Permian LLC

Statement of Operations

For the Year Ended December 31, 2015

 

Revenues:

  

Oil, natural gas and natural gas liquids sales

   $ 10,099,815   

Other

     (2,722
  

 

 

 

Total revenue

   $ 10,097,093   
  

 

 

 

Operating Expenses:

  

Lease operating expenses

     2,354,581   

Production and ad valorem taxes

     684,937   

Transportation and processing

     384,154   

Abandonments and dry hole costs

     72,283   

General and administrative

     6,449,319   

Depreciation, depletion and amortization

     3,626,862   

Gain on sale of oil and gas properties

     (2,498,321
  

 

 

 

Total costs and expenses

   $ 11,073,815   
  

 

 

 

Operating loss

   $ (976,722

Other expense:

  

Interest expense

     (87,133
  

 

 

 

Loss before income taxes

   $ (1,063,855

Texas margin tax

     242,298   
  

 

 

 

Net loss

   $ (1,306,153
  

 

 

 

The accompanying notes are an integral part of these financial statements.

 

5


Double Eagle Energy Permian LLC

Statement of Changes in Members’ Equity

For the Year Ended December 31, 2015

 

     Members’ Equity  

Balance at December 31, 2014

   $ 19,543,055   

Net income (loss)

     (1,306,153

Capital contributions

     79,560,637   

Capital distributions

     (3,408,703

Parent company net investment

     134,229,103   
  

 

 

 

Balance at December 31, 2015

   $ 228,617,939   
  

 

 

 

The accompanying notes are an integral part of these financial statements.

 

6


Double Eagle Energy Permian LLC

Statement of Cash Flows

For the Year Ended December 31, 2015

 

Cash flows from operating activities:

  

Net loss

   $ (1,306,153

Adjustments to reconcile net loss to net cash used in operating activities:

  

Depreciation, depletion and amortization

     3,626,862   

Amortization of deferred financing costs

     13,893   

Deferred Texas margin tax

     242,298   

Abandonment and dry hole costs

     72,283   

Gain on sale of oil and gas properties

     (2,498,321

Changes in operating assets and liabilities:

  

Accounts receivable

     (4,671,732

Other assets

     10,017   

Accounts payable and accrued liabilities

     191,686   

Accounts payable to related parties

     23,014   
  

 

 

 

Net cash used in operating activities

   $ (4,296,153
  

 

 

 

Cash flows from investing activities:

  

Purchase of oil and gas properties and development expenditures

   $ (189,441,118

Proceeds from sale of oil and gas properties

     14,771,936   

Advances to operators

     (89,521
  

 

 

 

Net cash used in investing activities

   $ (174,758,703
  

 

 

 

Cash flows from financing activities:

  

Borrowings under long-term debt

   $ 30,410,000   

Principal payments on long-term debt

     (14,210,000

Capital contributions

     29,127,144   

Capital distributions

     (3,408,703

Payment for deferred loan origination costs

     (145,861

Parent company net investment

     134,229,103   
  

 

 

 

Net cash provided by financing activities

   $ 176,001,683   
  

 

 

 

Net increase (decrease) in cash

   $ (3,053,173

Cash – Beginning of year

   $ 3,053,173   
  

 

 

 

Cash – End of year

   $ —     
  

 

 

 

Non-cash transactions:

  

Contributed Property

   $ 50,433,493   

The accompanying notes are an integral part of these financial statements.

 

7


Double Eagle Energy Permian LLC

Notes to the Financial Statements

 

1. ORGANIZATION AND NATURE OF BUSINESS

Description of the business and formation

Double Eagle Energy Permian LLC’s (the “Company,” “DEEP,” “we,” “our,” “us”), a Delaware limited liability company, was formed on September 29, 2016 (“date of inception”). The Company’s principal business is crude oil and natural gas exploration, development and production with operations in the Midland Basin of West Texas in the United States. We are an independent energy company engaged in the acquisition, exploration, development and production of crude oil and natural gas properties. Our strategy is to be an operator in the Midland Basin with a focus on horizontal drilling. However, for the year ended December 31, 2015, our strategy was to participate in non-operated working interests in wells and drilling projects within designated areas of operation through the acquisition of leasehold interests.

On September 29, 2016, the Company was formed by contributions from Double Eagle Energy Holdco LLC (“DEEH”), a newly formed parent of Double Eagle Energy Operating II LLC (the “Parent,” “Double Eagle,” “DE”), of its wholly-owned subsidiary, Double Eagle Lone Star LLC (“Lone Star”) and a third party, Veritas Energy Partners Holdings, LLC (“Veritas”), of its wholly owned subsidiary, Veritas Energy Partners, LLC (“Veritas Sub”). DEEH and DE are also wholly owned subsidiaries of Double Eagle Energy Holdings II LLC, (“DEEH II”) where all the board decisions and assets relating to Lone Star were historically managed.

Following the contribution of assets, DEEH held approximately 70% of DEEP’s equity, with Veritas holding the remaining 30%. The transactions between DEEH, DE, Lone Star and DEEH II were treated as a reorganization of entities under common control (as defined by U.S. GAAP), while Veritas’ contribution was treated as an acquisition of Veritas by DEEP. The financial statements included herein and associated notes and operations reflect the change in reporting entity and therefore are presented as if the Company existed and owned the assets since their acquisitions by DE. Lone Star was conveyed and recorded by the Company at DE’s respective historical carrying amounts. Certain amounts recorded and presented at DE that had not previously been allocated to the Company have been allocated to the Company to fairly present the financial results of the Company on a standalone basis. These allocations were performed utilizing systematic methods based on the operations of Lone Star.

For the year ended December 31, 2015, the balance sheet includes all specific oil and gas assets, current assets, current liabilities and asset retirement obligations of Lone Star, and those assets that were specifically tracked within the entity. In addition to the specific assets of Lone Star, management allocated debt and the associated deferred financing costs related to the debt that had previously been entered into, and accounted for, by the Parent. These allocations were based on a ratio of oil and gas assets of Lone Star as compared to the total oil and gas assets of the Parent. Management deemed this allocation method appropriate given the capital intensive nature of its business, and the correlation of the capital expenditures to the reserve-based borrowing facility. On September 30, 2016, immediately following the closing of the Veritas Acquisition, and in connection with the Parent’s redetermination on its existing loan agreement, the Company’s joint and several liability related to the Parent debt was removed. As a result, Company entered into a new reserve-based lending agreement guaranteed by the underlying assets of DEEP. As a result of these events, there is no Parent debt allocated to the standalone financials of DEEP as of and for any period subsequent to September 30, 2016. See “Note 4. Long-Term Debt” for further discussion regarding the indebtedness of the Company.

The statement of operations for the year ended December 31, 2015 also includes allocations for certain general and administrative expenses, stock-based compensation and interest expenses. All other costs and expenses were tracked at the individual asset level, and no allocations were necessary. The allocation method selected by management for these costs was based on the ratio of oil and gas assets at Lone Star to the total oil and gas of the Parent; DEEP’s allocation rate based on oil and gas assets was 73.14% (the “Allocation Percentage”). No revenue was allocated to the Company, from the Parent or otherwise.

 

8


2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation – The accompanying financial statements and related notes present the balance sheet as of December 31, 2015, and the statement of operations, changes in members’ equity and cash flows for the year then ended. Certain transactions between the Company and DEEH, as well as DE, together referred to as the Parent, have been presented in these financial statements as Parent company contributions as they are considered to be effectively settled at the time each transaction is recorded and there is no expectation of repayment by DEEP. The total net effect of the settlement of these transactions is reflected in the statement of members’ equity and Parent company net investment as net transfers (to)/from Parent, in the statement of cash flows as a financing activity and in the Company’s balance sheet as Parent company net investment. Unless otherwise stated, all amounts contained within the financial statements and accompanying notes are the responsibility of the Company, either as they were incurred by the Company through normal operations or were allocated to the Company from DE or DEEH.

The accompanying financial statements were prepared in accordance with U.S. generally accepted accounting principles (“GAAP”). Our financial statements include the accounts of the Company.

The Company’s financial statements include allocations of certain assets, liabilities and operating expenses historically held or incurred by the Parent, including equity-based compensation and other general and administrative expenses incurred by the Parent on behalf of its wholly owned subsidiaries, of which the Company is included.

Use of Estimates – The preparation of financial statements under GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Estimates and judgments are based on information available at the time such estimates and judgments are made. Although management believes the estimates are appropriate, actual results may differ from those estimates.

The most significant estimates pertain to proved oil and natural gas reserves and related cash flow estimates used in impairment tests of long-lived assets, estimates of future development, dismantlement and abandonment costs, estimates relating to certain oil and natural gas revenues and expenses and estimates of expenses related to legal, environmental and other contingencies. Certain of these estimates require assumptions regarding future commodity prices, future costs and expenses and future production rates. Actual results could differ from those estimates.

Estimates of oil and natural gas reserves and their values, future production rates and future costs and expenses are inherently uncertain for numerous reasons, including many factors beyond the Company’s control. Reservoir engineering is a subjective process of estimating underground accumulations of 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 data available and of engineering and geological interpretation and judgment. In addition, estimates of reserves may be revised based on actual production, results of subsequent exploration and development activities, prevailing commodity prices, operating costs and other factors. These revisions may be material and could materially affect future depreciation, depletion and amortization (“DD&A”) expense, dismantlement and abandonment costs, and impairment expense.

Cash and cash equivalents – During 2015, the Company consolidated treasury functions at the Parent to reduce the number of entities that were able to make payments or receive cash related to the operations of the business. Due to the change, the Company was no longer required to carry its own cash on its balance sheet, as shown by there being no cash on the accompanying balance sheet as of December 31, 2015. Cash transactions performed by the Parent, that directly related to the operations and activity of DEEP, have been presented in the statement of cash flows as if they were transactions of DEEP. Any amounts that will not be cash settled between DEEP and the Parent are treated as contributions and distributions in the accompanying Statement of Members’ Equity and Cash Flow Statement and in addition are included in the “Parent Company Net Investment” line.

Accounts Receivable – Accounts receivable are carried on a gross basis, with no discounting. The Company regularly reviews all aged accounts receivable for collectability and establishes an allowance as necessary for individual customer balances. As the Company has not experienced any credit losses, no allowance for doubtful accounts was recorded as of December 31, 2015.

 

9


Advances to Operators – The Company participates in the drilling of crude oil and natural gas wells with other working interest partners. Currently, the majority of the wells in which the Company participates are operated by unrelated third parties. Due to the capital intensive nature of crude oil and natural gas drilling activities, the operator of the well may request advance payments from other working interest partners for their share of the costs. The Company expects such advances to be applied by the operator against future development costs.

Oil and gas properties – The Company utilizes the successful efforts method of accounting for its oil and gas properties. Under this method, costs of acquiring properties, costs of drilling successful exploration wells, and development costs are capitalized. The costs of exploratory wells are initially capitalized pending a determination of whether proved reserves have been found. At the completion of drilling activities, the costs of exploratory wells remain capitalized if determination is made that proved reserves have been found. If no proved reserves have been found, the costs of each of the related exploratory wells are charged to expense. In some cases, a determination of proved reserves cannot be made at the completion of drilling, requiring additional testing and evaluation of the wells. The costs of such exploratory wells are expensed if a determination of proved reserves has not been made within a twelve-month period after drilling is complete. Exploration costs such as geological, geophysical, and seismic costs are expensed as incurred.

The capitalized costs of proved properties are depleted using the unit-of-production method based on proved developed or total proved reserves, as applicable. Costs of significant nonproducing properties, wells in the process of being drilled and development projects are excluded from depletion until the related project is completed and proved reserves are established or, if unsuccessful, impairment is determined.

Proceeds from the sales of individual properties and the capitalized costs of individual properties sold or abandoned are credited to the net book value of the amortization group, if doing so does not materially impact the depletion rate of an amortization base. Generally, no gain or loss is recognized until an entire amortization base is sold. However, gain or loss is recognized from the sale of less than an entire amortization base if the disposition is significant enough to materially impact the depletion rate of the remaining properties in the amortization base.

The Company performs assessments of its long-lived assets to be held and used, including proved oil and gas properties accounted for under the successful efforts method of accounting, whenever events or circumstances indicate that the carrying value of those assets may not be recoverable. An impairment loss is indicated if the sum of the expected future cash flows is less than the carrying amount of the assets. In these circumstances, the Company recognizes an impairment loss for the amount by which the carrying amount of the assets exceeds the estimated fair value of the assets. Estimating future cash flows involves the use of judgments, including estimation of the proved and unproved oil and gas reserve quantities, timing of development and production, expected future commodity prices, capital expenditures and production costs. We consider the inputs utilized in determining the fair value related to the impairment of long-lives assets to be Level 3 measurements in the fair value hierarchy. Since inception, the Company has not realized any impairments of its proved properties.

Unproved oil and gas properties are periodically assessed for impairment on a project-by-project basis. These impairment assessments are affected by the results of exploration activities, commodity price outlooks, planned future sales or expirations of all or a portion of such projects. If the estimated future net cash flows attributable to such projects are not expected to be sufficient to fully recover the costs invested in each project, the Company will recognize an impairment loss at that time. As of December 31, 2015, the Company had not realized any impairments of its unproved property. However, for the year ended December 31, 2015, the Company recognized approximately $61,000 related to lease expirations on its unproved properties, which are included in abandonment and dry hole costs on the statement of operations.

The Company capitalizes interest on expenditures for significant exploration and development projects that last more than six months while activities are in progress to bring the assets to their intended use. For the year ended December 31, 2015, the Company has not capitalized any interest as projects generally lasted less than six months.

Asset Retirement Obligations – Asset retirement obligations relate to future costs associated with the plugging and abandonment of crude oil and natural gas wells, removal of equipment and facilities from leased acreage and returning the land to its original condition. Estimates are based on estimated remaining lives of those wells based on reserve estimates, external estimates to plug and abandon the wells in the future, inflation, credit adjusted discount rates and federal and state regulatory requirements. We record the fair value of a liability for an asset retirement

 

10


obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. The liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Accretion expense is included in “Depreciation, depletion and amortization” on our statement of operations.

The estimated fair value of the Company’s asset retirement obligations at inception is determined by utilizing the income approach by applying a credit-adjusted risk-free rate, which takes into account the Company’s credit risk, the time value of money, and the current economic state, to the undiscounted expected abandonment cash flows. Given the unobservable nature of the inputs, the measurement of the asset retirement obligations was classified as Level 3 in the fair value hierarchy.

Deferred Financing Costs – Deferred financing costs include origination, legal and other fees to obtain or issue debt. These costs are deferred and reported on the balance sheet at cost, net of amortization. As the Company’s debt agreement is limited to lines of credit, total deferred financing costs are amortized on a straight line basis, which approximates the effective interest method, to interest expense over the term of the associated debt.

Revenue Recognition – The Company recognizes crude oil, natural gas and natural gas liquids (“NGLs”) revenues from its interests in producing wells when production is delivered to, and title has transferred to, the purchaser and to the extent the selling price is reasonably determinable. The Company uses the sales method of accounting for natural gas balancing of natural gas production and would recognize a liability if the existing proven reserves were not adequate to cover the current imbalance situation. As of December 31, 2015, the Company’s natural gas production was in balance, meaning its cumulative portion of natural gas production taken and sold from wells in which it has an interest was materially consistent with its entitled interests in natural gas production from wells.

Concentrations of Credit Risk – As of December 31, 2015, the Company’s primary market consists of operations in the Midland Basin of West Texas in the United States. The Company has concentration of oil and gas production revenues and receivables due from the operators of wells in which we hold non-operated working interests. Our exposure to non-payment or non-performance by the operators, our customers and counterparties presents a credit risk. Generally, non-payment or nonperformance results from a customer’s or counterparty’s inability to satisfy obligations. We monitor the creditworthiness of our customers and counterparties and established credit limits according to our credit policies and guidelines, but cannot assure that any losses will be consistent with our expectations.

Furthermore, the concentration of our customers in the energy industry may impact our overall exposure to credit risk as customers may be similarly affected by prolonged changes in economic and industry conditions. The Company actively pursues to invest in non-operated wells with financially stable and experienced operators in the respective areas of exploration, development and production. Although the Company is exposed to a concentration of credit risk, management believes the loss of revenue from any one customer would not significantly affect the Company’s financial or operational performance.

For the year ended December 31, 2015, the following third-party operators accounted for a significant portion of the Company’s total revenue:

 

     For the Year Ended
December 31, 2015
 

Permian Resources, LLC

     28

Crownquest Operating, LLC

     22

Encana Corporation

     15

Apache Corporation

     15

Qstar, LLC

     9
  

 

 

 
     89
  

 

 

 

Equity-Based Compensation – Prior to the formation and inception of DEEP, the Parent had issued its own Series B Units (the “Parent Incentive Units”) to certain employees of the Parent. The expense associated with the Parent Incentive Unit’s recorded at the Parent has been allocated to the Company and included in general and administrative expense in the accompanying statement of operations. See further discussion regarding the Parent’s B Units and the allocation of associated expense in “Note 6. Equity-Based Compensation”.

 

11


Fair Value Hierarchy – Fair value represents the price that would be received to sell the asset or paid to transfer the liability in an orderly transaction between market participants at the reporting date. The Company’s assets and liabilities that are measured at fair value at each reporting date are classified according to a hierarchy that prioritizes inputs and assumptions underlying the valuation techniques. This fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities and the lowest priority to unobservable inputs, and consists of three broad levels:

 

    Level 1—Assets and liabilities recorded at fair value for which values are based on unadjusted quoted prices for identical assets or liabilities in an active market that management has the ability to access. Active markets are considered to be those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

 

    Level 2—Assets and liabilities recorded at fair value for which values are based on quoted prices in markets that are not active or model inputs that are observable either directly or indirectly for substantially the full term of the asset or liability. Substantially all of these inputs are observable in the marketplace throughout the full term of the price risk management instrument and can be derived from observable data or supported by observable levels at which transactions are executed in the marketplace.

 

    Level 3—Assets and liabilities recorded at fair value for which values are based on prices or valuation techniques that require inputs that are both unobservable and significant to the overall fair value measurement. Unobservable inputs that are not corroborated by market data. These inputs generally reflect management’s own assumptions about the assumptions a market participant would use in pricing the asset or liability.

Valuation techniques that maximize the use of observable inputs are favored. Assets and liabilities are classified in their entirety based on the lowest priority level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the fair value hierarchy.

Recently Issued Accounting Standards

Leases . In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-02, Leases (Topic 842), which revises the accounting for leases by requiring certain leases to be recognized as assets and liabilities in the balance sheet, and requiring companies to disclose additional information about their leasing arrangements. We expect to adopt the provisions of this standard effective January 1, 2019. The Company is currently evaluating the new guidance and has not determined the impact, if any, this standard may have on our financial statements.

Revenue recognition . In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). The objective of ASU 2014-09 is greater consistency and comparability across industries by using a five-step model to recognize revenue from customer contracts. ASU 2014-09 also contains some new disclosure requirements under GAAP. In August 2015, the FASB issued Accounting Standards Update No. 2015-14, Deferral of the Effective Date (“ASU 2015-14”). ASU 2015-14 defers the effective date of the new revenue standard by one year, making it effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. In 2016, the FASB issued additional accounting standards updates to clarify the implementation guidance of ASU 2014-09. The Company is currently evaluating the method of adoption as well as the effect that adopting this guidance will have on its financial position, cash flows and results of operations.

Going concern . In August 2014, the FASB issued Accounting Standards Update No. 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (“ASU 2014-15”). ASU 2014-15 codifies in GAAP management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern and to provide related footnote disclosures. ASU 2014-15 is effective for the annual reporting period ending after December 15, 2016 and for annual periods and interim periods thereafter. The Company will adopt this guidance in fiscal year 2016.

 

12


Income Taxes . In November 2015, FASB issued ASU 2015-17, Income Taxes (“ASU 2015-17”). ASU 2015-17 simplifies the presentation of deferred income taxes and requires deferred tax assets and liabilities be classified as noncurrent in the balance sheet. The amendments in this ASU are effective for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years, and early adoption is permitted. Entities can transition to the standard either retrospectively to each period presented or prospectively. The Company is currently evaluating the new guidance, but does not anticipate the standard will have a material impact on our financial statements.

Imputation of Interest . In April 2015, FASB issued ASU 2015-03, Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs (“ASU 2015-03”). ASU 2015-03 requires debt issuance costs related to a recognized debt liability to be presented as a direct reduction of the carrying amount of that debt in the balance sheet, consistent with the presentation of debt discounts. The amendments in this ASU are effective for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years, and early adoption is permitted. Entities will be required to apply the guidance on a retrospective basis to each period presented as a change in accounting principle. In August 2015, the FASB issued ASU 2015-15, Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs (“ASU 2015-15”) which amends ASU 2015-03 to clarify the presentation and subsequent measurement of debt issuance costs associated with line of credit arrangements, such that entities may continue to apply current practice. The Company will adopt this guidance in fiscal year 2016. The amended guidance must be applied on a retrospective basis and will not materially impact the Company’s financial statements.

 

3. ACQUISITIONS

The Company accounts for acquisitions of proved property as business combinations and, accordingly, the results of operations are included in the accompanying statement of operations from the closing date of the acquisition.

Laredo Transaction

On September 15, 2015, the Company completed the acquisition of approximately 6,100 net acres of producing and non-producing leasehold properties for purchase price of $65.2 million, subject to customary purchase price adjustments. The Company accounted for the acquisition as a business combination in accordance with ASC 805. The transaction included $15.9 million in Proved – Producing reserves.

At the time of the acquisition, the properties included 117 producing wells and two wells in development. The Company held non-significant non-operated working interest in the producing wells. The properties were located in Glasscock and Reagan County Texas in the Midland Basin.

The allocation of the adjusted purchase price is as follows:

 

Adjusted Purchase price:

  

Cash

   $ 65,220,000   
  

 

 

 

Total Adjusted Purchase price

   $ 65,220,000   
  

 

 

 

Allocation of Purchase price:

  

Proved – Producing

   $ 15,940,000   

Proved and unproved – Acreage

     49,280,000   
  

 

 

 

Total Allocated Purchase price

   $ 65,220,000   
  

 

 

 

The Company also incurred $133,801 in asset retirement obligations related to this acquisition. Transaction costs of approximately $45,600 were recognized in “General and administrative” expenses in the accompanying statement of operations for the year ended December 31, 2015.

In addition, the Company acquired other unproved and proved property in transactions throughout the year.

 

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4. LONG-TERM DEBT

On February 2, 2015, the Parent entered into a credit agreement, partially secured by the assets of the Company, with Wells Fargo Bank, N.A. (“RBL Loan”). The debt instrument, a Reserves Based Loan (“RBL”), provides for revolving credit loans to be made and letters of credit to be issued from time to time for the account of the Parent. The aggregate amount of the commitment from Wells Fargo is $250.0 million.

As the credit facility was partially secured by the assets of the Company, DEEP previously had a financial obligation to repay the Parent for any borrowings made on its behalf, requiring an allocation of the borrowing base and outstanding borrowings. As of December 31, 2015, the Company’s allocated share of the borrowing base was $32.4 million, of which there was an allocated outstanding balance of $16.2 million outstanding in borrowings and $125,000 outstanding letters of credit under the RBL Loan. The Company’s allocated debt balances were based on a percentage of Lone Star’s asset value, as defined in the RBL agreement, which approximates fair value, to the total asset value of all collateral securing the RBL. Management believes this allocation method provides a reasonable allocation methodology for the Parent’s debt and associated interest expense at December 31, 2015. Obligations under the RBL were secured by a first-priority security interest in substantially all of the Parent’s proved reserves. In addition, obligations under the RBL were guaranteed by the Parent’s operating subsidiaries, of which the Company is listed.

The weighted average interest rate was 2.06% for the year ended December 31, 2015. The commitment fee was 0.375% on undrawn balances of the RBL as of December 31, 2015.

The following is the principal maturity schedule for the Company’s allocated balance of the RBL as of December 31, 2015:

 

     For the year ended
December 31,
 

2016

   $ —     

2017

     —     

2018

     —     

2019

     —     

2020

     16,200,000   

Thereafter

     —     
  

 

 

 
   $ 16,200,000   
  

 

 

 

The accompanying balance sheet includes the Company’s allocated portion of deferred financing fees related to the RBL, net of amortization, of approximately $132,000. For the year ended December 31, 2015, the company recognized approximately $14,000 in amortization expense related to the deferred financing fees, which is included in interest expense on the accompanying statement of operations.

The RBL, entered into by the Parent as discussed above, was extinguished on September 30, 2016 and replaced with a debt facility entered into by the Company. See Note 12 – Subsequent Events for further discussion.

 

5. ASSET RETIREMENT OBLIGATIONS

The carrying amount of the Company’s ARO on the Company’s balance sheet at December 31, 2015 was $1.1 million. At the inception of drilling activities, the Company determines the ARO by calculating the present value of estimated future cash flows related to the liability if a reasonable estimate of fair value can be made and the corresponding cost is capitalized as part of the carrying amount of the related long-lived asset. Estimating the future ARO requires management to make estimates and judgments regarding the timing and existence of a liability, as well as what constitutes adequate restoration when considering current regulatory requirements. Inherent in the fair value calculation are numerous assumptions and judgments, including the ultimate costs, inflation factors, credit adjusted discount rates, timing of settlement and changes in the legal, regulatory, environmental and political environments. These assumptions represent Level 3 inputs. To the extent future revisions to these assumptions impact the fair value of the existing ARO liability, a corresponding adjustment is made to the related asset.

The following table provides a reconciliation of the changes in the asset retirement obligations generally associated with future costs associated with the plugging and abandonment of crude oil and natural gas wells,

 

14


removal of equipment and facilities from leased acreage and returning the land to its original condition for the period indicated:

 

     For the year ended
December 31, 2015
 

Beginning asset retirement obligations

   $ 6,789   

Liability incurred

     80,561   

Changes in estimates

     829,846   

Acquisitions

     133,801   

Accretion expense

     4,485   
  

 

 

 

Ending asset retirement obligations

   $ 1,055,482   
  

 

 

 

The changes in estimates of $829,846 is a result of declining commodity prices during 2015 that resulted in decreases to the estimated future economic life of the related wells.

As of December 31, 2015, no assets are legally restricted for use in settling asset retirement obligations, and all obligations are classified as long-term in the balance sheet as we do not expect to incur any of these charges within the next year.

 

6. MEMBERS’ EQUITY AND EQUITY-BASED COMPENSATION

On November 12, 2014, the Parent entered into a limited liability company agreement (“LLC Agreement”) with its Management Group and a private equity financial sponsor (“the PE Sponsor”) with an initial capital commitment of $165.0 million. The Parent was formed with a conveyance of subsidiaries from Double Eagle Holdings and cash contributions from the PE Sponsor and the Management Group. Certain employees of Double Eagle Holdings (“Other Management Members”) who held profit interests were distributed Series A Units in the Company which constituted their respective distributed value of the assets transferred. The Other Management Members that obtained Series A Units in the Parent through their profit interest in Double Eagle Holdings will not participate in future contributions.

On September 13, 2015, an Election Letter was executed pursuant to Section 5.02(g) of the LLC Agreement whereas the PE Sponsor exercised its right to increase its commitments to the Parent through ANRP Double Eagle Holdings II, L.P., an affiliate of the PE Sponsor. The PE Sponsor’s commitment amount is $175.0 million to the Parent. In addition on September 13, 2015, the Management Group executed an Election Letter pursuance to Section 5.02(g) of the LLC Agreement whereas the Management Group elected to increase their commitment to the Parent in the amount of $39.4 million.

As of December 31, 2015, The PE Sponsor, The PE Sponsor II and the Management Group have contributed $286.2 million to Double Eagle. As of December 31, 2015, Double Eagle had remaining capital commitments of $93.4 million from the PE Sponsor and the Management Group.

Prior to the formation and inception of DEEP, the Parent had issued its own Series B Units (the “Parent Incentive Units”) to certain employees of the Parent. As of December 31, 2015, the Parent had issued 985 Series B Units of which 784 were outstanding and unvested. The weighted average grant date fair value of the Series B Units is $10,600 per unit. These Parent Incentive Units are tied to certain performance metrics and return hurdles of the Parent and its wholly owned subsidiaries including, but not limited to, DEEP. Eighty percent of the Parent Incentive Units vest monthly over a four-year period, with the remaining twenty percent only vesting upon a liquidity event, as defined in the Parent’s Limited Liability Company Agreement. The Parent accounts for these units as equity awards in accordance with ASC 718 and records expense related to these awards based on the grant date fair value of the awards. These units are unrelated to the ownership and Series B Units granted by DEEP during 2016. The financial obligation or payout requirements of the Parent Incentive Units belongs to the Parent.

As the employees who were awarded Parent Incentive Units provided services to the assets associated with the Company during 2015, a portion of the cost associated with the Parent Incentive Units has been allocated to the Company, as discussed below.

 

15


For the year ending December 31, 2015, approximately $1.4 million of the expense associated with the Parent Incentive Unit’s recorded at the Parent has been allocated to the Company and included in general and administrative expense in the accompanying statement of operations. The expense was allocated during these periods based on the allocation of total capitalized oil and gas properties between Lone Star and Rockies at each period end. This methodology is consistent with the treatment of other statement of operation items from the Parent that were identified to be allocated to the Company for standalone presentation. The offset to the allocated expense will be included in Parent Company Net Investment, a members’ equity account of the Parent reflecting their invested balance in the Company.

 

7. FAIR VALUE MEASUREMENT

In accordance with the FASB’s authoritative guidance on fair value measurements, the Company’s financial assets and liabilities are measured at fair value on a recurring basis. The book value of the Company’s current assets and liabilities approximate their fair value due to the short-term nature of the instruments. The Company recognizes its non-financial assets and liabilities, such as ARO and proved oil and natural gas properties upon impairment, at fair value on a non-recurring basis. As of December 31, 2015, the Company did not record an impairment on any of its oil and natural gas properties. See Note 5 – Asset Retirement Obligations above for further discussion on the Company’s ARO.

The Company has not elected to account for any assets or liabilities using the fair value option under ASC 825-10.

 

8. INCOME TAXES

Income Taxes – The Company is not subject to federal or state income taxes, except as noted below, as we are organized as a partnership for income tax purposes and the results of operations are taxable directly to the members. Accordingly, each member is responsible for its share of federal and state income tax.

Texas Margin Tax – The Company is subject to the Texas Margin Tax that requires tax payments at a maximum statutory effective rate of 0.75% on the taxable margin of each taxable entity that does business in Texas. The margin tax qualifies as an income tax under Accounting Standards Codification 740, Income Taxes (FAS 109/FIN 48) (“ASC 740”), which requires us to recognize currently the impact of this tax on the temporary differences between the financial statement assets and liabilities and their tax basis attributable to such tax. For the year ended December 31, 2015, the Company has a greater apportionment rate in Texas as well as greater temporary differences between GAAP and taxable income. As such, for the year ended December 31, 2015, the Company recognized a deferred tax liability in the amount of approximately $0.3 million related to the Texas Margin Tax which is included in the accompanying balance sheet.

Uncertain Tax Positions – We evaluate the uncertainty in tax positions taken or expected to be taken in the course of preparing our financial statements to determine whether the tax positions are more likely than not of being sustained by the applicable tax authority. Tax positions with respect to tax at the partnership level deemed not to meet the more likely than not threshold would be recorded as a tax benefit or expense in the current year. We believe that there are no uncertain tax positions that would impact our operations for the year ended December 31, 2015, and that no provision for income tax is required for these financial statements. However, our conclusions regarding the evaluation are subject to review and may change based on factors including, but not limited to, ongoing analyses of tax laws, regulations and interpretations thereof. With all tax positions meeting the “more likely than not” threshold under ASC 740, the Company determined that there is no current effect on the financial statements from a lapse of the statute of limitations as it relates to unrecognized tax benefits. Additionally, the Company’s tax year 2015 remain open for examination. As of December 31, 2015, the Company has no amounts related to accrued interest and penalties.

 

16


9. RELATED PARTY TRANSACTIONS

The PE Sponsor, a leading global alternative investment manager, has a substantial equity investment in us and has three individuals on our Board of Directors. The PE Sponsor’s investment in and relationship with us qualifies them as a related party. The Parent of the Company is party to several agreements with the PE Sponsor, as follows:

Transaction Fee

The Parent is party to a Transaction Fee Agreement, dated November 12, 2014 with an affiliate of the PE Sponsor which requires us to pay 1% of the total equity contributed to Double Eagle by the PE Sponsor pursuant to a merger or acquisition of equity or assets if such contribution by The PE Sponsor is $25.0 million or greater (“Transaction Fee”), in exchange for their oversight and expertise related to the financing and completion of such transactions. For the year ended December 31, 2015, any Transaction Fee that could have been incurred by the Company has been waived by the PE Sponsor.

Services Agreement

The Parent is party to a consulting and advisory services agreement (“Services Agreement”) which requires us to compensate the PE Sponsor equal to the greater of (i) 1% of earnings before interest, income taxes, depletion, depreciation, amortization and exploration expense per quarter, and (ii) $65,200 per quarter (the “Consulting Fee”). The Services Agreement also provides for reimbursement to the PE Sponsor for any reasonable out-of-pocket. . For the year ended December 31, 2015, the Parent incurred approximately $273,300, in Consulting Fees and out-of-pocket expenditures, of which the Company was allocated $200,000, which are included in “General and administrative” expenses in the accompanying statement of operations. As of December 31, 2015, approximately $148,300 was recorded at the Parent, of which $108,000 was allocated to the Company and included in accounts payable to related parties in the accompanying balance sheet.

Certain members of management and entities owned and controlled by those members of management have certain agreements with the Parent, whereas consideration is paid to those members or their controlled entities for services performed or use of commonly owned assets, as follows:

Shared Services Agreement

The Parent is party to an agreement with a management member’s entity whereas this entity provides certain general and administrative services to Double Eagle Energy Holdings II LLC (“Shared Services Agreement”) for a monthly fee of approximately $14,500 (“Shared Services Expense”). For the year ended December 31, 2015, the Parent incurred approximately $174,500 in Shared Services Expense, of which approximately $128,000, was allocated to the Company, which is included in general and administrative expense in the accompanying statement of operations. As of December 31, 2015, no expenses related to the Shared Services Agreement were included in accounts payable to related parties in the accompanying balance sheet.

Management Services Agreement

The Parent entered into an agreement with another entity owned by the PE Sponsor and management whereas the employees of the Parent would provide employment services to them for a monthly fee of approximately $15,000. For the year ended December 31, 2015, the Parent billed a total of $180,000 related to the services performed for the related affiliate, of which approximately $131,000 was allocated to the Company and included as an offset to general and administrative expense in the accompanying statement of operations. As of December 31, 2015, $45,000 was recorded at the Parent, of which approximately $33,000 was allocated to the Company and included accounts receivable in the accompanying balance sheet.

Office Lease Agreement

On February 1, 2015 the Parent enter a lease agreement with a management member’s entity whereas the Parent leases office space for general business activity for a period of three years at a monthly rate of $13,200. Rental rates were determined based on comparable rates charged by third parties in surrounding areas. The Company’s allocated portion of this expense was approximately $108,000 for the year ended December 31, 2015, and is included in general and administrative expense in the accompanying statement of operations. As of December 31, 2015, no expenses related to the office lease agreement were included in accounts payable to related parties in the accompanying balance sheet. See Note 11 – Commitments and Contingencies for further discussion.

 

17


Use of an airplane

The Company rented an airplane for business use for certain members of Company at various times from a management member’s entity. The airplane is part of a shared fleet, and managed by a third party that invoices the Company for its use based on the operated plane hours at market rate with associated flight crew charges. The Company’s allocated portion of this expense was approximately $130,800 for the year ended December 31, 2015, and is included in general and administrative expense in the accompanying statement of operations. As of December 31, 2015, approximately $12,000 related to the agreement were included in accounts payable to related parties in the accompanying balance sheet.

Acquisitions / Contributions of oil and gas properties

From time to time, the Company acquires oil and gas properties from other management members’ controlled entities. These transactions are based on the fair value of the assets that are purchased between the Company and a related party. In certain instances, the Company reimburses service costs incurred that related to the acquisition of these assets. For the year ended December 31, 2015, the Company incurred costs to management members’ controlled entities of approximately $10.4 million for oil and gas properties and associated service costs, of which approximately $1.89 million is included in accounts payable to related parties on the accompanying balance sheet.

In addition to cash purchases, management members have the ability to offset cash capital contributions with contributions of oil and gas properties. Other management members’ controlled entities have similar oil and gas operations in the Midland Basin and these entities have been in existence prior to the formation of the Company. During 2015, management identified certain assets that were directly accretive to the asset base of the Company, and thus contributed these properties alongside cash capital calls from the PE Sponsor. The value derived for the contributions were based on applicable market comps, fair value, for similar assets in the Midland Basin. During 2015, approximately $50.4 million in identified oil and gas properties were contributed to the Company in exchange for equity interests.

 

10. COMMITMENTS AND CONTINGENCIES

Litigation – From time-to-time we are party to certain legal, regulatory or administrative proceedings that arise in the ordinary course and are incidental to our business. As of December 31, 2015, there are no such pending proceedings to which we are party to that our management believes will have a material adverse effect on our results of operations, cash flows or financial condition. However, future events or circumstances, currently unknown to management, will determine whether the resolution of any litigation or claims will ultimately have a material effect on our results of operations, cash flows or financial condition in any future reporting periods.

Casualties and Other Risks – The Company maintains coverage in various insurance programs, which provide us with property damage and other coverage which are customary for the nature and scope of our operations.

The Company believes we have adequate insurance coverage, although insurance will not cover every type of loss that might occur. As a result of insurance market conditions, premiums and deductibles for certain insurance policies could increase significantly, and in certain instances, insurance may become unavailable, or available at reduced coverage.

If we were to incur a significant loss for which we were not adequately insured, the loss could have a material impact on our results of operations, cash flow or financial condition. In addition, the proceeds of any available insurance may not be paid in a timely manner and may be insufficient if such an event were to occur. Any event that interrupts our revenues, or which causes us to make a significant expenditure not covered by insurance, could reduce our ability to meet future financial obligations.

 

18


Commitments – The following table summarizes our commitments and obligations as of December 31, 2015:

 

    

 

     Payments Due by Period  
     Total      2016      2017      2018      2019      2020      Thereafter  

Operating Leases(1)

   $ 330,000       $ 158,400       $ 158,400       $ 13,200       $ —         $ —         $ —     

Deferred lease acquisition costs(2)

     740,000         185,000         185,000         185,000         185,000         —           —     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total

   $ 1,070,000       $ 343,400       $ 343,400       $ 198,200       $ 185,000       $ —         $ —     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

 

1 The Parent leases office buildings under operating leases, as discussed above in Note 9 – Related Party Transactions . The lease was renewed on February 1, 2015, at a monthly rate of $13,200, and terminates on January 31, 2018. We recognized approximately $108,000 in rental expense, allocated from the Parent, for the year ended December 31, 2015. After September 30, 2016, the Company will begin to incur the entirety of the monthly rent expense as the lone wholly owned subsidiary of the Parent.
2 During 2014, the Company entered into an agreement whereas a certain oil and gas lease was assigned to the Company in exchange for five equal annual installment payments of $185,000 to the assignor of the lease. Each annual payment is due by January 15th of the respective year. The Company includes the short term portion of the liability in accounts payable and accrued liabilities and the long term portion in deferred lease acquisition costs in the accompanying balance sheet.

 

11. DEFINED CONTRIBUTION PLAN

The Company participates in a 401(k) defined contribution plan sponsored by the Parent, for the benefit of all employees at their date of hire. The plan allows eligible employees to contribute a portion of their annual compensation, not to exceed annual limits established by the federal government. The Parent makes matching contribution of up to a certain percentage of an employee’s contributions. For the year ended December 31, 2015, the Company was allocated contributions to the plan of approximately $66,000 from the Parent.

 

12. SUBSEQUENT EVENTS

On April 21, 2016, the Company entered into a Membership Interest Purchase and Sale Agreement (“MIPSA”) with MCM Energy Partners, LLC (“MCM”), whereas the Company acquired eight-five percent (85%) of the membership interest of Novus Land Services, LLC (“Novus”). For the consideration for the sale, assignment, transfer and conveyance of the acquired interest, the Company paid MCM approximately $19.2 million in aggregate, representing 85% of the fair value of the assets and liabilities as of the closing date. The acquisition was concluded to be treated as a business combination per ASC 805, Business Combinations, under the acquisition method as noted in ASC 805-10-05-4. The assets and liabilities held by Novus, as well as the results of its operations will be consolidated into the financial statements issued by the Company for all periods subsequent to the acquisition date. The acquisition is expected to comprise less than 5% of the future annual pre-tax income and net assets of the Company.

On February 3, 2017, the Company entered into another MIPSA whereas the Company purchased the remaining fifteen percent (15%) non-controlling interest in Novus Land Services, LLC. The Company paid consideration in the amount of $14.6 million for the 15% ownership. The acquisition will be subject to customary due diligence and post-closing matters.

On September 29, 2016, to align its business operations with management’s revised strategy to become an operator with a focus on horizontal drilling, the Parent entered into an LLC agreement whereas the Parent contributed all of the ownership interests in a wholly owned subsidiary (“Lone Star”) to the Company in exchange for Series A-1 units representing an approximate 70% interest in DEEP. Veritas Energy Partners Holdings, LLC (“Veritas”), a third party, contributed all of the ownership interests of its wholly owned subsidiary, Veritas Energy Partners, LLC (“Veritas Energy”) to DEEP in exchange for Series A-1 units representing an approximate 30% interest in DEEP (the “Veritas Acquisition”). Following the Veritas Acquisition, Veritas Energy ceased to exist as a standalone entity. The assets, liabilities and results of operations of Veritas Energy for the period ended December 31, 2015 are not included in, or otherwise consolidated with, the accompanying financial statements, nor described in the accompanying notes, contained herein. At closing, DEEP will recorded the assets and liabilities of Veritas Energy at their respective fair values.

 

19


The following table summarizes the fair values of assets acquired and liabilities assumed, as of September 29, 2016. The preliminary purchase price allocation is as follows:

 

Condensed Balance Sheet of Assets Acquired and Liabilities Assumed

 

Current assets

  

Cash and cash equivalents

   $ 6,777,181   

Accounts receivable

     2,674,057   

Other current assets

     154,656   
  

 

 

 

Total current assets

     9,605,894   

Oil and gas properties

  

Proved oil and gas properties

     38,941,679   

Unproved oil and gas properties

     277,722,754   
  

 

 

 

Total fair value of oil and gas properties acquired

     316,664,433   

Liabilities assumed

  

Accounts payable and accrued liabilities

     4,815,078   

Asset retirement obligation

     686,800   
  

 

 

 

Consideration transferred

   $ 320,768,449   
  

 

 

 

The final purchase price allocation is pending the completion of the valuation of the assets and liabilities exchanged.

On September 30, 2016, in order to fund the Veritas Acquisition and execute on the Company’s revised business strategy, the Company entered into a credit agreement with JPMorgan Chase Bank, N.A. (“JPMorgan”), with a maximum revolving credit facility of $500.0 million with an initial borrowing base of $60.0 million (“JPM Revolver”). However, the Company’s ability to draw on the JPM Revolver is limited by an Indenture Agreement between the Company and an additional capital provider and related affiliates (“Capital Provider”), as discussed below, thereby effectively reducing the borrowing base. The JPM Revolver is secured by liens on substantially all of the Company’s properties and guarantees from the Company’s subsidiaries. The Credit Agreement of the JPM Revolver contains restrictive covenants that may limit our ability to, among other things, issue or incur additional indebtedness, enter into mergers, make investments or enter into hedging contracts. With the issuance of the JPM Revolver, the debt allocated to the Company under the Wells Fargo RBL, entered into by the Parent, was extinguished. The unamortized portion of the related deferred financing fees previously allocated to the company, approximately $187,000, were fully amortized on this date and included in the statement of operations.

Upon execution of the Credit Agreement, we were required to provide evidence satisfactory to the JPMorgan that we had entered into hedge agreements, as defined, covering at least 50% of reasonably anticipated production for each month through December 31, 2017. During the period which the Credit Agreement is in effect, hedged volumes may not exceed 85% of the reasonably anticipated production (based on forecasts from reserve reports acceptable to the Administrative Agent) for any 66 month period from the creation of the most recent Hedging Agreement. The Credit Agreement also specifies the hedge agreements may not be entered into for speculative purposes. Prior to this requirement, the Company had not participated in hedging activities.

On November 7, 2016, DEEP entered into a Unit Subscription Agreement (the “Subscription Agreement”), with the Capital Provider, to sell units in DEEP, representing approximately 7.5% of DEEP’s equity interests, to the Capital Provider for $150 million. The Company amended the LLC Agreement to provide for the issuance of Series C Units, to be awarded by and with the approval of the Board of Directors, to create a new class of Capital Interest Members of the Company. In connection with the equity issued pursuant to the Subscription Agreement, the Capital Provider affiliates are entitled to certain liquidation preferences in the event of a liquidity event or certain asset sales, as defined in the Subscription Agreement.

In conjunction with the Unit Subscription Agreement with the Capital Provider, 73,876,046 of Series C Units in DEEP, representing approximately 7.5% of DEEP’s equity interests, were sold to the Capital Provider for $150 million. The Series C Units entitle holders to participate in the net profits of the Company; however, holders of Series C Units do not possess voting rights or the right to consent or approve any action or matter. In the event of a liquidation of the Company, the Capital Provider’s Series C Units entitle them to a preferred return, contingent on presence of certain facts. Upon the closing of the Subscription Agreement, the equity interests in DEEP held by DEEH, Veritas and the Capital Provider were approximately 64.75%, 27.75% and 7.5%, respectively.

In addition to the Company’s equity offering to the Capital Provider, on November 7, 2016 DEEP and the Capital Provider also entered into a Senior Notes Purchase Agreement whereby DEEP may issue and sell to the Capital Provider up to $300.0 million in 8.75% senior unsecured notes, due in 2022 (the “Capital Provider Notes”). The Capital Provider Notes may be issued between November 7, 2016 and December 31, 2017 (the “Commitment Period”) in series of not less than $100.0 million per issue. Borrowings, pursuant to draw down requests as defined in the Senior Note Purchase Agreement, may not be less than $100.0 million and are subject to a 1% original issue

 

20


discount (“OID”), and are limited by debt covenants and an Indenture Agreement also imposing restrictions on the Company’s ability to borrow additional debt. The Capital Provider Notes are also subject to a contingent commitment fee, payable in cash, equal to the lesser of $12 million or 4.00% of any of the unfunded $300.0 million commitment that is not issued by the end of the Commitment Period. As of February 4, 2017, no amounts were drawn on the Capital Provider Notes, however no contingency was recognized for the Capital Provider Notes contingency, as the probability of incurring the cost could not be determined by Management.

We have evaluated subsequent events through February 4, 2017, the date the financial statements were available to be issued.

 

21


DOUBLE EAGLE ENERGY PERMIAN LLC

Supplemental Information

(Unaudited)

 

13. SUPPLEMENTAL OIL AND GAS RESERVE INFORMATION – UNAUDITED

The reserve estimates at December 31, 2015 presented in the tables below are based on reports prepared by Cawley, Gillespie & Associates, Inc., the Company’s independent reserve engineers, in accordance with the SEC rules on oil and gas reserve estimation and disclosures. In accordance with SEC requirements, the pricing used by the Company is based on the 12-month unweighted arithmetic average of the first-day-of-the-month spot price for the period January through December and adjusted by lease for quality, transportation, geographical differentials, marketing bonuses or deductions and other factors affecting the price received at the wellhead. The use of SEC pricing rules may not be indicative of actual prices realized by the Company in the future. The commodity prices, based on SEC pricing and inclusive of adjustments for quality and location used in determining future net revenues related to the standardized measure calculation, are as follows:

 

     As of
December 31, 2015
 

Oil (NYMEX price per Bbl)

   $ 48.56   

Natural Gas (Henry Hub price per Mcf)

   $ 2.19   

Natural Gas Liquids (per Engineering report per Bbl)

   $ 11.93   

During 2015, all of the Company’s oil and natural gas producing activities were conducted within the state of Texas.

Oil and natural gas reserve quantity estimates are subject to numerous uncertainties inherent in the estimation of quantities of proved reserves, the projection of future production rates and the timing of future development expenditures. The Company emphasizes that reserve estimates are inherently imprecise and that estimates of new discoveries and undeveloped locations are more imprecise than estimates of established proved producing oil and natural gas properties. Accordingly, these estimates are expected to change as future information becomes available.

Proved oil and natural gas reserves are the estimated quantities of oil and natural gas that geological and engineering data demonstrate, with reasonable certainty, to be recoverable in future years from known reservoirs under economic and operating conditions (i.e., prices and costs) existing at the time the estimate is made. Proved developed oil and natural gas reserves are proved reserves that can be expected to be recovered through existing wells and equipment in place and under operating methods being utilized at the time the estimates were made.

Estimated Quantities of Proved Oil and Natural Gas Reserves

The following table sets forth the Company’s estimated net proved, proved developed and proved undeveloped reserves at December 31, 2015:

 

     Oil
(MBbl)
     Gas
(MMcf)
     NGL
(MBbl)
     Mboe  

Total Proved Reserves

           

Balance, beginning of period

     325.6         668.3         140.2         577.1   

Revisions of previous estimates

     32.4         171.2         47.6         108.5   

Extensions, discoveries and other additions

     4,080.7         6,749.8         1,336.1         6,541.8   

Purchase of reserves in place

     2,434.5         5,417.8         817.0         4,154.5   

Production

     (204.2      (455.7      (72.0      (352.2

Sales of reserves in place

     —           —           —           —     
  

 

 

    

 

 

    

 

 

    

 

 

 

Net proved reserves in place at December 31, 2015

     6,669.0         12,551.4         2,268.9         11,029.8   
  

 

 

    

 

 

    

 

 

    

 

 

 

Proved developed reserves, December 31, 2015

     3,779.0         7,552.7         1,244.5         6,282.3   
  

 

 

    

 

 

    

 

 

    

 

 

 

Proved undeveloped reserves, December 31, 2015

     2,890.0         4,998.7         1,024.4         4,747.5   
  

 

 

    

 

 

    

 

 

    

 

 

 

 

22


Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Natural Gas Reserves

The Standardized Measure of Discounted Future Net Cash Flows and Changes Therein Relating to Proved Oil and Natural Gas Reserves (“Standardized Measure”) does not purport to present the fair market value of our oil and natural gas properties. An estimate of such value should consider, among other factors, anticipated future prices of oil and natural gas, the probability of recoveries in excess of existing proved reserves, the value of probable reserves and acreage prospects, and perhaps different discount rates. It should be noted that estimates of reserve quantities, especially from new discoveries, are inherently imprecise and subject to substantial revision.

The Company’s estimated net proved reserves and related future net revenues and Standardized Measure were determined using index prices for oil and natural gas, which are held constant throughout the life of the properties. Future operating costs, production taxes and development costs were based on current costs as of December 31, 2015.

The following table sets forth the Standardized Measure of discounted future net cash flows from projected production of the Company’s estimated net proved oil and natural gas reserves:

 

     As of
December 31, 2015
 

Future cash inflows

   $ 378,377,494   

Future production costs

     (135,651,011

Future development costs

     (67,529,421

Future income tax expense

     (730,787
  

 

 

 

Future net cash flows

   $ 174,466,275   

10% annual discount for estimated timing of cash flows

     (91,171,475
  

 

 

 

Standardized measure of discounted future net cash flows

   $ 83,294,800   
  

 

 

 

Future net cash flows do not include the effects of U.S. federal income taxes on future results because the Company is a limited liability company not subject to entity-level federal income taxes. Accordingly, no provision for federal corporate income taxes has been provided because taxable income was passed through to the Company’s equity holders. However, the Company’s operations are located in Texas are subject to an entity-level tax, the Texas Margin Tax, at a statutory rate of up to 0.75% of income that is apportioned to Texas.

The following table sets forth the changes in the Standardized Measure of discounted future net cash flows applicable to estimated net proved reserves:

 

     As of
December 31, 2015
 

Balance, beginning of period

   $ 8,710,760   

Sales of oil and natural gas produced during the period, net

     (7,097,380

Net changes in prices and production costs

     (3,032,837

Sale of reserves in place

     —     

Purchases of reserves in place

     38,870,812   

Net changes due to extensions & discoveries

     42,327,784   

Development costs incurred during the year

     2,421,583   

Net changes in future development costs

     (2,651,370

Net changes due to revisions of previous quantity estimates

     2,897,378   

Accretion of discount

     876,247   

Changes in timing and other

     280,953   

Net change in income taxes

     (309,130
  

 

 

 

Standardized measure of discounted future net cash flows

   $ 83,294,800   
  

 

 

 

 

23

Exhibit 99.6

 

LOGO

Consolidated Financial Statements

(Unaudited)

For the Period Ending

September 30, 2016


DOUBLE EAGLE ENERGY PERMIAN LLC

INDEX TO THE CONSOLIDATED FINANCIAL STATEMENTS

 

     Page  

Consolidated Balance Sheet As of September 30, 2016

     3   

Consolidated Statement of Operations For the Nine Months Ended September 30, 2016

     4   

Consolidated Statement of Cash Flows For the Nine Months Ended September 30, 2016

     5   

Notes to the Consolidated Financial Statements

     6   

 

2


Double Eagle Energy Permian LLC

Consolidated Balance Sheet

As of September 30, 2016

( Unaudited )

 

Assets

  

Current assets:

  

Cash and cash equivalents

   $ 11,321,887   

Restricted cash

     1,488,872   

Accounts receivable

     12,806,809   

Advances to operators

     2,031,552   

Other current assets

     161,543   
  

 

 

 

Total current assets

     27,810,663   

Property and equipment:

  

Oil and gas properties, successful efforts method of accounting:

  

Proved properties

     193,692,792   

Unproved properties

     589,507,875   
  

 

 

 

Total oil and gas properties

     783,200,667   

Less: Accumulated depreciation, depletion and amortization

     (12,358,192
  

 

 

 

Total oil and gas properties, net

     770,842,475   
  

 

 

 

Total assets

   $ 798,653,138   
  

 

 

 

Liabilities and Members’ Equity

  

Current liabilities:

  

Accounts payable and accrued liabilities

   $ 17,802,862   

Accrued oil and gas development expenditures

     8,378,173   

Short-term debt

     383,127   
  

 

 

 

Total current liabilities

     26,564,162   

Texas margin tax

     2,256,417   

Deferred lease acquisition costs

     370,000   

Long-term debt

     1,372,872   

Asset retirement obligations

     2,291,157   

Members’ equity

     761,281,995   

Non-controlling interest

     4,516,535   
  

 

 

 

Total liabilities and equity

   $ 798,653,138   
  

 

 

 

The accompanying notes are an integral part of these consolidated financial statements.

 

3


Double Eagle Energy Permian LLC

Consolidated Statement of Operations

For the Nine Months Ended

September 30, 2016

( Unaudited )

 

Revenues:

  

Oil, natural gas and natural gas liquids sales

   $ 24,414,729  

Other

     322,575  
  

 

 

 

Total revenue

     24,737,304  
  

 

 

 

Operating Expenses:

  

Lease operating expenses

     5,738,691  

Production and ad valorem taxes

     1,554,289  

Transportation and processing

     1,140,216  

Abandonments of oil and gas properties

     2,276,245  

General and administrative

     7,850,211  

Depreciation, depletion and amortization

     8,280,846  

Loss on sale of oil and gas properties

     2,792,847  
  

 

 

 

Total costs and expenses

     29,633,345  
  

 

 

 

Operating loss

     (4,896,041

Other expense:

  

Interest

     (1,250,223
  

 

 

 

Loss before income taxes

     (6,146,264

Texas margin tax

     (242,404

Net loss

     (6,388,668
  

 

 

 

Net loss attributable to non-controlling partner

     27,763  
  

 

 

 

Net loss attributable to Double Eagle Energy Permian LLC

   $ (6,360,905
  

 

 

 

The accompanying notes are an integral part of these consolidated financial statements.

 

4


Double Eagle Energy Permian LLC

Consolidated Statement of Cash Flows

For the Nine Months Ended

September 30, 2016

(Unaudited)

 

Cash flows from operating activities:

  

Net loss

   $ (6,388,668

Adjustments to reconcile net loss to net cash provided by operating activities:

  

Depreciation, depletion and amortization

     8,280,846   

Amortization of deferred financing costs

     131,968   

Texas margin tax expense

     242,404   

Abandonment of oil and gas properties

     2,276,245   

Loss on sale of oil and gas properties

     2,792,847   

Changes in operating assets and liabilities:

  

Accounts receivable

     (3,130,940

Accounts payable and accrued liabilities

     9,603,152   

Accounts payable to related parties

     (1,977,282
  

 

 

 

Net cash provided by operating activities

     11,830,572   
  

 

 

 

Cash flows from investing activities:

  

Purchase of oil and gas properties and development expenditures

     (154,485,181

Proceeds from sale of oil and gas properties

     6,567,028   

Advances to operators

     (1,942,031
  

 

 

 

Net cash used in investing activities

     (149,860,184
  

 

 

 

Cash flows from financing activities:

  

Borrowings under long-term debt

     9,839,000   

Principal payments on long-term debt

     (26,198,636

Capital contributions

     12,648,696   

Parent company net investment

     153,062,439   
  

 

 

 

Net cash provided by financing activities

     149,351,499   
  

 

 

 

Net increase in cash

     11,321,887   

Cash - Beginning of period

     —     
  

 

 

 

Cash - End of period

   $ 11,321,887   
  

 

 

 

Non-cash transactions:

  

Contributed Property

   $ 35,508,013   

Veritas Contributed Property

   $ 316,664,433   

The accompanying notes are an integral part of these consolidated financial statements.

 

5


Double Eagle Energy Permian LLC

Notes to the Consolidated Financial Statements

(Unaudited)

 

1. ORGANIZATION AND NATURE OF BUSINESS

Description of the business and formation

Double Eagle Energy Permian LLC’s (the “Company,” “DEEP,” “we,” “our,” “us”), a Delaware limited liability company, was formed on September 29, 2016 (“date of inception”). The Company’s principal business is crude oil and natural gas exploration, development and production with operations in the Midland Basin of West Texas in the United States. We are an independent energy company engaged in the acquisition, exploration, development and production of crude oil and natural gas properties. Our strategy is to be an operator in the Midland Basin with a focus on horizontal drilling. However, for the year ended December 31, 2015, our strategy was to participate in non-operated working interests in wells and drilling projects within designated areas of operation through the acquisition of leasehold interests.

On September 29, 2016, the Company was formed by contributions from Double Eagle Energy Holdco LLC (“DEEH”), a newly formed parent of Double Eagle Energy Operating II LLC (the “Parent,” “Double Eagle,” “DE”), of its wholly-owned subsidiary, Double Eagle Lone Star LLC (“Lone Star”) and a third party, Veritas Energy Partners Holdings, LLC (“Veritas”), of its wholly owned subsidiary, Veritas Energy Partners, LLC (“Veritas Sub”). DEEH and DE are also wholly owned subsidiaries of Double Eagle Energy Holdings II LLC (“DEEH II”), where all the board decisions and assets relating to Lone Star were historically managed.

Following the contribution of assets, DEEH held approximately 70% of DEEP’s equity, with Veritas holding the remaining 30%. The transactions between DEEH, DE, Lone Star and DEEH II were treated as a reorganization of entities under common control (as defined by U.S. GAAP), while Veritas’ contribution was treated as an acquisition of Veritas by DEEP. The financial statements included herein and associated notes and operations reflect the change in reporting entity and therefore are presented as if the Company existed and owned the assets since their acquisitions by DE. Lone Star was conveyed and recorded by the Company at DE’s respective historical carrying amounts. Certain amounts recorded and presented at DE that had not previously been allocated to the Company have been allocated to the Company to fairly present the financial results of the Company on a standalone basis. These allocations were performed utilizing systematic methods based on the operations of Lone Star.

As of September 30, 2016 the consolidated balance sheets includes all specific Lone Star and Veritas assets and liabilities, where those items were specifically tracked within the entity. Previously, the Parent allocated debt and the related deferred financing fees associated with DEEP’s operations from the Parent. These allocations were based on a ratio of oil and gas assets of Lone Star as compared to the total oil and gas assets of the Parent. Management deemed this allocation method appropriate given the capital intensive nature and operating metrics for the business. As of September 29, 2016, the Company completed the reorganization and related consolidated balance sheet amounts represented the Company’s assets and liabilities exclusive of the Parent. In addition, on September 30, 2016, the Company obtained its own form of financing and no longer provided collateral to the Parent’s debt. See Note 4 - Long Term Debt for further discussion of the Company’s debt facility.

The consolidated statements of operations for the nine months ended September 30, 2016 includes allocations for certain general and administrative expenses, stock-based compensation and interest expenses. All other costs and expenses were tracked at the individual asset level, and no allocations were necessary. The allocation method selected by management for these costs was based on the ratio of oil and gas assets at Lone Star to the total oil and gas of the Parent. No revenue was allocated to the Company, from the Parent or otherwise, for any of the before mentioned periods.

DEEP’s allocation based on oil and gas assets for the nine months ended September 30, 2016 was allocated cumulatively by quarters across three month periods ended March 31, 2016, June 30, 2016 and September 30, 2016 at 66%, 78% and 88%, respectively.

 

6


2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation – The accompanying consolidated financial statements and related notes present the consolidated balance sheets as of September 30, 2016, and the consolidated statements of operations for nine months ended September 30, 2016 and cash flows for the period then ended. All intracompany transactions occurring between the Company entities have been eliminated. Certain transactions between the Company and DEEH, as well as DE, together referred to as the Parent, have been presented in these consolidated financial statements as Parent company contributions as they are considered to be effectively settled at the time each transaction is recorded and there is no expectation of repayment by DEEP. The total net effect of the settlement of these transactions is reflected in the Parent company net investment as net transfers (to)/from Parent, in the consolidated statements of cash flows as a financing activity and in the Company’s consolidated balance sheets as Parent company net investment. Unless otherwise stated, all amounts contained within the consolidated financial statements and accompanying notes are the responsibility of the Company, either as they were incurred by the Company through normal operations or were allocated to the Company from DE or DEEH.

The accompanying consolidated financial statements were prepared in accordance with U.S. generally accepted accounting principles (“GAAP”). Our consolidated financial statements include the accounts of the Company.

The Company’s consolidated financial statements include allocations of certain assets and liabilities historically held at DEEH and DE, including the proportionate debt, and related interest expense, equity-based compensation and other general and administrative expenses incurred by DE to fund the operations and purchase of assets for DEEP.

Use of Estimates – The preparation of consolidated financial statements under GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Estimates and judgments are based on information available at the time such estimates and judgments are made. Although management believes the estimates are appropriate, actual results may differ from those estimates.

The most significant estimates pertain to proved oil and natural gas reserves and related cash flow estimates used in impairment tests of long-lived assets, estimates of future development, dismantlement and abandonment costs, estimates relating to certain oil and natural gas revenues and expenses and estimates of expenses related to legal, environmental and other contingencies. Certain of these estimates require assumptions regarding future commodity prices, future costs and expenses and future production rates. Actual results could differ from those estimates.

Estimates of oil and natural gas reserves and their values, future production rates and future costs and expenses are inherently uncertain for numerous reasons, including many factors beyond the Company’s control. Reservoir engineering is a subjective process of estimating underground accumulations of 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 data available and of engineering and geological interpretation and judgment. In addition, estimates of reserves may be revised based on actual production, results of subsequent exploration and development activities, prevailing commodity prices, operating costs and other factors. These revisions may be material and could materially affect future depreciation, depletion and amortization (“DD&A”) expense, dismantlement and abandonment costs, and impairment expense.

Cash and cash equivalents – As of September 30 2016, we consider all highly liquid investments with a remaining maturity of three months or less at the time of purchase to be cash or cash equivalents. Cash equivalents consist of cash in a short-term money market account. During 2015, the Company consolidated treasury functions at the Parent to reduce the number of entities that were able to make payments or receive cash related to the operations of the business. Cash transactions performed by the Parent, that directly related to the operations and activity of DEEP, have been presented in the statement of cash flows as if they were transactions of DEEP. Any amounts that will not be cash settled between DEEP and the Parent were treated as Parent company contributions and distributions in the accompanying Cash Flow Statement and in addition are included in the “Parent Company Net Investment” line.

 

7


Accounts Receivable – Accounts receivable are carried on a gross basis, with no discounting. The Company regularly reviews all aged accounts receivable for collectability and establishes an allowance as necessary for individual customer balances. As the Company has not experienced any credit losses, no allowance for doubtful accounts was recorded as of September 30, 2016.

Advances to Operators – The Company participates in the drilling of crude oil and natural gas wells with other working interest partners. Currently, the majority of the wells in which the Company participates are operated by unrelated third parties. Due to the capital intensive nature of crude oil and natural gas drilling activities, the operator of the well may request advance payments from other working interest partners for their share of the costs. The Company expects such advances to be applied by the operator against future development costs.

Oil and gas properties – The Company utilizes the successful efforts method of accounting for its oil and gas properties. Under this method, costs of acquiring properties, costs of drilling successful exploration wells, and development costs are capitalized. The costs of exploratory wells are initially capitalized pending a determination of whether proved reserves have been found. At the completion of drilling activities, the costs of exploratory wells remain capitalized if determination is made that proved reserves have been found. If no proved reserves have been found, the costs of each of the related exploratory wells are charged to expense. In some cases, a determination of proved reserves cannot be made at the completion of drilling, requiring additional testing and evaluation of the wells. The costs of such exploratory wells are expensed if a determination of proved reserves has not been made within a twelve-month period after drilling is complete. Exploration costs such as geological, geophysical, and seismic costs are expensed as incurred.

The capitalized costs of proved properties are depleted using the unit-of-production method based on proved developed or total proved reserves, as applicable. Costs of significant nonproducing properties, wells in the process of being drilled and development projects are excluded from depletion until the related project is completed and proved reserves are established or, if unsuccessful, impairment is determined.

Proceeds from the sales of individual properties and the capitalized costs of individual properties sold or abandoned are credited to the net book value of the amortization group, if doing so does not materially impact the depletion rate of an amortization base. Generally, no gain or loss is recognized until an entire amortization base is sold. However, gain or loss is recognized from the sale of less than an entire amortization base if the disposition is significant enough to materially impact the depletion rate of the remaining properties in the amortization base.

The Company performs assessments of its long-lived assets to be held and used, including proved oil and gas properties accounted for under the successful efforts method of accounting, whenever events or circumstances indicate that the carrying value of those assets may not be recoverable. An impairment loss is indicated if the sum of the expected future cash flows is less than the carrying amount of the assets. In these circumstances, the Company recognizes an impairment loss for the amount by which the carrying amount of the assets exceeds the estimated fair value of the assets. Estimating future cash flows involves the use of judgments, including estimation of the proved and unproved oil and gas reserve quantities, timing of development and production, expected future commodity prices, capital expenditures and production costs. We consider the inputs utilized in determining the fair value related to the impairment of long-lives assets to be Level 3 measurements in the fair value hierarchy. Since inception, the Company has not realized any impairments of its proved properties.

Unproved oil and gas properties are periodically assessed for impairment on a project-by-project basis. These impairment assessments are affected by the results of exploration activities, commodity price outlooks, planned future sales or expirations of all or a portion of such projects. If the estimated future net cash flows attributable to such projects are not expected to be sufficient to fully recover the costs invested in each project, the Company will recognize an impairment loss at that time. For nine months ended September 30, 2016, the Company had not realized any impairments of its unproved property, but did incur $2.3 million in abandonment costs in the period.

The Company capitalizes interest on expenditures for significant exploration and development projects that last more than six months while activities are in progress to bring the assets to their intended use. For the nine months ended September 30, 2016, the Company has not capitalized any interest as projects generally lasted less than six months.

 

8


Asset Retirement Obligations – Asset retirement obligations relate to future costs associated with the plugging and abandonment of crude oil and natural gas wells, removal of equipment and facilities from leased acreage and returning the land to its original condition. Estimates are based on estimated remaining lives of those wells based on reserve estimates, external estimates to plug and abandon the wells in the future, inflation, credit adjusted discount rates and federal and state regulatory requirements. We record the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. The liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Accretion expense is included in “Depreciation, depletion and amortization” on our Consolidated Statements of Operations.

The estimated fair value of the Company’s asset retirement obligations at inception is determined by utilizing the income approach by applying a credit-adjusted risk-free rate, which takes into account the Company’s credit risk, the time value of money, and the current economic state, to the undiscounted expected abandonment cash flows. Given the unobservable nature of the inputs, the measurement of the asset retirement obligations was classified as Level 3 in the fair value hierarchy.

Deferred Financing Costs – Deferred financing costs include origination, legal and other fees to obtain or issue debt. These costs are deferred and reported on the consolidated balance sheets at cost, net of amortization. Total deferred financing costs are amortized on a straight line basis, which approximates the effective interest method, to interest expense over the term of the associated debt.

Revenue Recognition – The Company recognizes crude oil, natural gas and natural gas liquids (“NGLs”) revenues from its interests in producing wells when production is delivered to, and title has transferred to, the purchaser and to the extent the selling price is reasonably determinable. The Company uses the sales method of accounting for natural gas balancing of natural gas production and would recognize a liability if the existing proven reserves were not adequate to cover the current imbalance situation. As of September 30, 2016, the Company’s natural gas production was in balance, meaning its cumulative portion of natural gas production taken and sold from wells in which it has an interest was materially consistent with its entitled interests in natural gas production from wells.

Concentrations of Credit Risk – As of September 30, 2016, the Company’s primary market consists of operations in the Midland Basin of West Texas in the United States. The Company has concentration of oil and gas production revenues and receivables due from the operators of wells in which we hold non-operated working interests. Our exposure to non-payment or non-performance by the operators, our customers and counterparties presents a credit risk. Generally, non-payment or nonperformance results from a customer’s or counterparty’s inability to satisfy obligations. We monitor the creditworthiness of our customers and counterparties and established credit limits according to our credit policies and guidelines, but cannot assure that any losses will be consistent with our expectations.

Furthermore, the concentration of our customers in the energy industry may impact our overall exposure to credit risk as customers may be similarly affected by prolonged changes in economic and industry conditions. The Company actively pursues to invest in non-operated wells with financially stable and experienced operators in the respective areas of exploration, development and production. Although the Company is exposed to a concentration of credit risk, management believes the loss of revenue from any one customer would not significantly affect the Company’s financial or operational performance.

Equity-Based Compensation – Equity-based compensation expense is recognized on Series B Units that are expected to participate in future profits of the Company upon a liquidity event. The fair value of the units on the grant date is recorded to expense as the units vest. The amount of equity-based compensation expense recognized at any date is approximately equal to the ratable portion of the grant date value of the award that is vested as of that date. See further discussion regarding the Company’s B Units and equity-based compensation in Note 6 – Member’s Equity and Equity-Based Compensation.

 

9


Fair Value Hierarchy – Fair value represents the price that would be received to sell the asset or paid to transfer the liability in an orderly transaction between market participants at the reporting date. The Company’s assets and liabilities that are measured at fair value at each reporting date are classified according to a hierarchy that prioritizes inputs and assumptions underlying the valuation techniques. This fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities and the lowest priority to unobservable inputs, and consists of three broad levels:

 

    Level 1—Assets and liabilities recorded at fair value for which values are based on unadjusted quoted prices for identical assets or liabilities in an active market that management has the ability to access. Active markets are considered to be those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

 

    Level 2—Assets and liabilities recorded at fair value for which values are based on quoted prices in markets that are not active or model inputs that are observable either directly or indirectly for substantially the full term of the asset or liability. Substantially all of these inputs are observable in the marketplace throughout the full term of the price risk management instrument and can be derived from observable data or supported by observable levels at which transactions are executed in the marketplace.

 

    Level 3—Assets and liabilities recorded at fair value for which values are based on prices or valuation techniques that require inputs that are both unobservable and significant to the overall fair value measurement. Unobservable inputs that are not corroborated by market data. These inputs generally reflect management’s own assumptions about the assumptions a market participant would use in pricing the asset or liability.

Valuation techniques that maximize the use of observable inputs are favored. Assets and liabilities are classified in their entirety based on the lowest priority level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the fair value hierarchy.

 

3.    ACQUISITIONS

The Company accounts for acquisitions of proved property as business combinations and, accordingly, the results of operations are included in the accompanying consolidated statements of operations from the closing date of the acquisition.

Veritas Acquisition

On September 29, 2016, the Parent, to align its business operations with management’s revised strategy to become an operator with a focus on horizontal drilling, entered into an LLC agreement whereas the Parent contributed all of the ownership interests in Lone Star to the Company in exchange for Series A-1 units representing an approximate 70% interest in DEEP. Veritas, a third party, contributed all of the ownership interests of its wholly owned subsidiary, Veritas Energy to DEEP in exchange for Series A-1 units representing an approximate 30% interest in DEEP. The following table summarizes the fair values of assets acquired and liabilities assumed, as of September 29, 2016.

The preliminary purchase price allocation is as follows:

 

Condensed Balance Sheet of Assets Acquired and Liabilities Assumed

 

Current assets

  

Cash and cash equivalents

   $ 6,777,181   

Accounts receivable

     2,674,057   

Other current assets

     154,656   
  

 

 

 

Total current assets

     9,605,894   

Oil and gas properties

  

Proved oil and gas properties

     38,941,679   

Unproved oil and gas properties

     277,722,754   
  

 

 

 

Total fair value of oil and gas properties acquired

     316,664,433   

Liabilities assumed

  

Accounts payable and accrued liabilities

     4,815,078   

Asset retirement obligation

     686,800   
  

 

 

 

Consideration transferred

   $ 320,768,449   
  

 

 

 

 

10


The final purchase price allocation is pending the completion of the Company’s valuation of the assets and liabilities exchanged.

 

4. LONG-TERM DEBT

On September 30, 2016, the Company entered into a Credit Agreement with JPMorgan Chase Bank, N.A. (“Credit Agreement”), as administrative agent (“Administrative Agent”), and a syndicate of lenders, with a maximum revolving credit facility of $500.0 million with an initial borrowing base of $60.0 million (“JPM Revolver”). The JPM Revolver is secured by liens on substantially all of the Company’s properties and guarantees from the Company’s subsidiaries. The Credit Agreement of the JPM Revolver contains restrictive covenants that may limit our ability to, among other things, issue or incur additional indebtedness, enter into mergers, make investments or enter into hedging contracts.

The amount available to be borrowed is subject to the borrowing base that is redetermined semi-annually each May and November, with such redetermination effective May 1 and November 1, respectively. The amount of the borrowing base depends on the volumes of our proved oil and natural gas reserves and estimated cash flows from these reserves and other information deemed relevant by the Administrative Agent. As of September 30, 2016, the effective borrowing base of the JPM Revolver was $25 million, of which none was drawn.

Upon execution of the Credit Agreement, we were required to provide evidence satisfactory to the Administrative Agent that we had entered into hedge agreements, as defined, covering at least 50% of reasonably anticipated production for each month through December 31, 2017. During the period which the Credit Agreement is in effect, hedged volumes may not exceed 85% of the reasonably anticipated production (based on forecasts from reserve reports acceptable to the Administrative Agent) for any 66 month period from the creation of the most recent Hedging Agreement. The Credit Agreement also specifies the hedge agreements may not be entered into for speculative purposes. There was no hedging activity as of September 30, 2016.

 

5. ASSET RETIREMENT OBLIGATIONS

The carrying amount of the Company’s ARO on the Company’s consolidated balance sheets at September 30, 2016 was $2.3 million. At the inception of drilling activities, the Company determines the ARO by calculating the present value of estimated future cash flows related to the liability if a reasonable estimate of fair value can be made and the corresponding cost is capitalized as part of the carrying amount of the related long-lived asset. Estimating the future ARO requires management to make estimates and judgments regarding the timing and existence of a liability, as well as what constitutes adequate restoration when considering current regulatory requirements. Inherent in the fair value calculation are numerous assumptions and judgments, including the ultimate costs, inflation factors, credit adjusted discount rates, timing of settlement and changes in the legal, regulatory, environmental and political environments. These assumptions represent Level 3 inputs. To the extent future revisions to these assumptions impact the fair value of the existing ARO liability, a corresponding adjustment is made to the related asset.

The following table provides a reconciliation of the changes in the asset retirement obligations generally associated with future costs associated with the plugging and abandonment of crude oil and natural gas wells, removal of equipment and facilities from leased acreage and returning the land to its original condition for the period indicated:

 

     Nine Months Ended
September 30, 2016
 

Beginning asset retirement obligations

   $ 1,055,482   

Liability incurred

     483,247   

Revisions in estimates

     —     

Acquisitions

     686,800   

Accretion expense

     65,628   
  

 

 

 

Ending asset retirement obligations

   $ 2,291,157   
  

 

 

 

 

11


As of September 30, 2016, no assets are legally restricted for use in settling asset retirement obligations, and all obligations are classified as long-term in the consolidated balance sheets as we do not expect to incur any of these charges within the next year.

 

6. MEMBERS’ EQUITY AND EQUITY-BASED COMPENSATION

Prior to the formation and inception of DEEP, the Parent had issued and outstanding 1,005 Series B Units of which 655 were unvested as of September 30, 2016. The weighted average grant date fair value of the Series B Units is $10,700 per unit. These Parent Incentive Units are tied to certain performance metrics and return hurdles of the Parent and its wholly owned subsidiaries including, but not limited to, DEEP. Eighty percent of the Parent Incentive Units vest monthly over a four-year period, with the remaining twenty percent only vesting upon a liquidity event, as defined in the Parent’s Limited Liability Company Agreement. The Parent accounts for these units as equity awards in accordance with ASC 718 and records expense related to these awards based on the grant date fair value of the awards. These units are unrelated to the ownership and Series B Units granted by DEEP. The financial obligation or payout requirements of the Parent Incentive Units belongs to the Parent.

As the employees who were awarded Parent Incentive Units provided services to the assets associated with the Company during 2015 and the first nine months of 2016, a portion of the cost associated with the Parent Incentive Units has been allocated to DEEP. However, as the employees migrated to DEEP subsequent to the Veritas Acquisition, beginning on October 1, 2016, 100% of the future expense is allocated to the consolidated statement of operations of the Company, as discussed below. For the nine months ending September 30, 2016, $1.2 million, respectively, of the expense associated with the Parent Incentive Unit’s recorded at the Parent has been allocated to the Company and included in general and administrative expense in the accompanying consolidated statement of operations.

As of September 29, 2016, the date of inception, DEEP issued Series A Units which represent the equity ownership of the Company and Series B Units which represent incentive units of the Company in accordance with Limited Liability Company Agreement (“LLC Agreement”). In addition, and in conjunction with the Second Amendment to the LLC Agreement, the Company issued Series C Units to another capital provider and related affiliates (“Capital Provider”). See below for specific disclosures related to the Company’s Series A, B and C Units. Prior to the formation and inception of DEEP, the Parent had issued its own Series B Units (the “Parent Incentive Units”) to certain employees of the Parent.

Series A Units – DEEP’s second amended LLC Agreement provides for the issuance of Series A Units, awarded to the two initial parties contributing assets during the formation of the Company at inception, as described herein, as Capital Interest Members of the Company. The Series A Units entitle holders to participate in the net profits of the Company, and grant voting rights and the right to consent or approve on all actions or matters of the Company. At completion of the Veritas Acquisition on September 29, 2016, whereas DEEH contributed all of its Lone Star assets and Veritas contributed its wholly owned subsidiary, Veritas Energy, to the Company, DEEH and Veritas were awarded 731,748,440 and 292,881,554 Series A shares, respectively, for DEEP’s acquisition of these assets. The Series A Units of DEEP have a par value of $1, whereas the initial value of DEEH and Veritas’ equity positions in DEEP are $731,748,440 and $292,881,554, respectively. DEEH’s contribution was governed by the rules pertaining to entities under common control, whereas Veritas’ contribution was an acquisition of by the Company. Immediately following the execution of the Veritas Acquisition, the equity interests in DEEP held by DEEH and Veritas were approximately 70.0% and 30.0%, respectively.

Series B Units – DEEP’s second amended LLC Agreement provides for the issuance of Series B Units, as determined and approved by the Board of Directors, to employees of the Company’s. The Series B Units entitle holders to participate in the net profits of the Company, but are subject to various service and performance criteria, and holders of Series B Units do not possess voting rights or the right to consent or approve any action or matter. Upon the occurrence of a liquidity event (as defined in the second amended LLC Agreement) and after the Series A and Series C Members’ capital contributions and Preference Amount has been satisfied, the remaining net profits will be distributed to the Series A, C and B Members in accordance with the terms of the LLC Agreement.

Series B Units vest 80% ratably over a four year period on an annual basis, with the remaining 20% vesting upon a liquidity event or initial public offering. Series B Units can also vest early upon the occurrence of a liquidity event, initial public offering or in some cases upon termination of employment with DEEP. The Company can issue

 

12


1,000,000 Series B Units pursuant to the second amended LLC Agreement upon approval by the Board of Directors. 110,000 Series B Units were issued members of the Company new management team on September 29, 2016, the date of inception.

As of September 30, 2016, the Company had approximately $1.1 million of total unrecognized compensation costs related to unvested Series B Units which is expected to be recognized over the remaining vesting term, which is approximately four years from the grant date.

 

7. INCOME TAXES

Income Taxes – The Company is not subject to federal or state income taxes, except as noted below, as we are organized as a partnership for income tax purposes and the results of operations are taxable directly to the members. Accordingly, each member is responsible for its share of federal and state income tax.

Texas Margin Tax – The Company is subject to the Texas Margin Tax that requires tax payments at a maximum statutory effective rate of 0.75% on the taxable margin of each taxable entity that does business in Texas. The margin tax qualifies as an income tax under Accounting Standards Codification 740, Income Taxes (FAS 109/FIN 48) (“ASC 740”), which requires us to recognize currently the impact of this tax on the temporary differences between the consolidated financial statement assets and liabilities and their tax basis attributable to such tax. For the year ended December 31, 2015, the Company has a greater apportionment rate in Texas as well as greater temporary differences between GAAP and taxable income. As such, as of September 30, 2016, the Company recognized a deferred tax liability in the amount of approximately $2.3 million related to the Texas Margin Tax which is included in the accompanying consolidated balance sheets.

Uncertain Tax Positions – We evaluate the uncertainty in tax positions taken or expected to be taken in the course of preparing our consolidated financial statements to determine whether the tax positions are more likely than not of being sustained by the applicable tax authority. Tax positions with respect to tax at the partnership level deemed not to meet the more likely than not threshold would be recorded as a tax benefit or expense in the current year. We believe that there are no uncertain tax positions that would impact our operations for the nine months ended September 30, 2016, and that no provision for income tax is required for these consolidated financial statements. However, our conclusions regarding the evaluation are subject to review and may change based on factors including, but not limited to, ongoing analyses of tax laws, regulations and interpretations thereof. With all tax positions meeting the “more likely than not” threshold under ASC 740, the Company determined that there is no current effect on the consolidated financial statements from a lapse of the statute of limitations as it relates to unrecognized tax benefits. Additionally, the Company’s tax years 2016 and 2015 remain open for examination. As of September 30, 2016, the Company has no amounts related to accrued interest and penalties.

 

8. SUBSEQUENT EVENTS

On November 7, 2016, DEEP entered into a Unit Subscription Agreement (the “Subscription Agreement”), with the Capital Provider and related affiliates (“Capital Provider”), to sell units in DEEP, representing approximately 7.5% of DEEP’s equity interests, to the Capital Provider for $150 million. The Company amended the LLC Agreement to provide for the issuance of Series C Units, to be awarded by and with the approval of the Board of Directors, to create a new class of Capital Interest Members of the Company. In connection with the equity issued pursuant to the Subscription Agreement, the Capital Provider affiliates are entitled to certain liquidation preferences in the event of a liquidity event or certain asset sales, as defined in the Subscription Agreement.

In conjunction with the Unit Subscription Agreement with the Capital Provider, 73,876,046 of Series C Units in DEEP, representing approximately 7.5% of DEEP’s equity interests, were sold to the Capital Provider for $150 million. The Series C Units entitle holders to participate in the net profits of the Company; however, holders of Series C Units do not possess voting rights or the right to consent or approve any action or matter. In the event of a liquidation of the Company, the Capital Provider’s Series C Units entitle them to a preferred return, contingent on presence of certain facts. Upon the closing of the Subscription Agreement, the equity interests in DEEP held by DEEH, Veritas and the Capital Provider were approximately 64.75%, 27.75% and 7.5%, respectively.

In addition to the Company’s equity offering to the Capital Provider, on November 7, 2016 DEEP and the Capital Provider also entered into a Senior Notes Purchase Agreement whereby DEEP may issue and sell to the

 

13


Capital Provider up to $300.0 million in 8.75% senior unsecured notes, due in 2022 (the “Capital Provider Notes”). The Capital Provider Notes may be issued between November 7, 2016 and December 31, 2017 (the “Commitment Period”) in series of not less than $100.0 million per issue. Borrowings, pursuant to draw down requests as defined in the Senior Note Purchase Agreement, may not be less than $100.0 million and are subject to a 1% original issue discount (“OID”), and are limited by debt covenants and an Indenture Agreement also imposing restrictions on the Company’s ability to borrow additional debt. The Capital Provider Notes are also subject to a contingent commitment fee, payable in cash, equal to the lesser of $1.2 million or 4.00% of any of the unfunded $300.0 million commitment that is not issued by the end of the Commitment Period. As of February 4, 2017, no amounts were drawn on the Capital Provider Notes, however no contingency was recognized for the Capital Provider Notes contingency, as the probability of incurring the cost could not be determined by Management.

Pursuant to the PSA and the Subscription Agreement, the Capital Provider and its affiliates are entitled to a preferred return in the event of a liquidation or sale of the Company. For the period beginning January 1, 2017 through July 31, 2017, an amount equal to a 15.0% premium to the price per share paid by the Capital Provider on November 7, 2016 to acquire their shares in the Company, less any prior distributions.

On February 3, 2017, the Company entered into a Membership Interest Purchase and Sale Agreement (“Membership Purchase Agreement”) whereas the Company purchased the fifteen percent non-controlling interest in Novus Land Services, LLC. The Company paid consideration in the amount of $14.6 million for the remaining fifteen percent ownership. The acquisition will be subject to customary due diligence and post-closing matters.

We have evaluated subsequent events through February 4, 2017, the date the financial statements were available to be issued.

 

14

Exhibit 99.7

UNAUDITED PRO FORMA CONSOLIDATED AND COMBINED FINANCIAL STATEMENTS

PARSLEY ENERGY, INC. AND SUBSIDIARIES

PRO FORMA CONSOLIDATED AND COMBINED BALANCE SHEETS AS OF SEPTEMBER 30, 2016

(in thousands)

 

    PE Historical     Double Eagle Acquisition     Pro forma adjustments           PE Pro forma  

ASSETS

         

CURRENT ASSETS

         

Cash and cash equivalents

  $ 571,762      $ 11,322      $ 1,400,000        (a   $ 549,798   
        (1,433,286     (b  

Restricted cash

    2,755        1,489        (1,489     (b     2,755   

Accounts receivable:

         

Joint interest owners and other

    13,708        2,031        —          (b     15,739   

Oil, natural gas and NGLs

    45,685        12,807        (12,807     (b     45,685   

Related parties

    331        —          —            331   

Short-term derivative instruments, net

    32,537        —          —            32,537   

Other current assets

    25,713        161        (161     (b     25,713   
 

 

 

   

 

 

   

 

 

     

 

 

 

Total current assets

    692,491        27,810        (47,743       672,558   
 

 

 

   

 

 

   

 

 

     

 

 

 

PROPERTY, PLANT AND EQUIPMENT

         

Oil and natural gas properties, successful efforts method

    3,435,514        783,201        2,024,169        (a     6,242,884   

Accumulated depreciation, depletion and impairment

    (450,387     (12,358     12,358        (b     (450,387
 

 

 

   

 

 

   

 

 

     

 

 

 

Total oil and natural gas properties, net

    2,985,127        770,843        2,036,527          5,792,497   
 

 

 

   

 

 

   

 

 

     

 

 

 

Other property, plant and equipment, net

    47,441        —          —            47,441   
 

 

 

   

 

 

   

 

 

     

 

 

 

Total property, plant and equipment, net

    3,032,568        770,843        2,036,527          5,839,938   
 

 

 

   

 

 

   

 

 

     

 

 

 

NONCURRENT ASSETS

         

Long-term derivative instruments, net

    21,017        —          —            21,017   

Deferred tax asset

    6,832        —          4,234        (a     11,066   

Other noncurrent assets

    3,564        —          —            3,564   
 

 

 

   

 

 

   

 

 

     

 

 

 

Total noncurrent assets

    31,413        —          4,234          35,647   
 

 

 

   

 

 

   

 

 

     

 

 

 

TOTAL ASSETS

    3,756,472        798,653        1,993,018          6,548,143   
 

 

 

   

 

 

   

 

 

     

 

 

 

LIABILITIES AND EQUITY

         

CURRENT LIABILITIES

         

Accounts payable and accrued expenses

    132,749        26,181        (26,181     (b     132,749   

Revenue and severance taxes payable

    57,926        —          —            57,926   

Current portion of long-term debt

    1,543        383        (383     (b     1,543   

Short-term derivative instruments

    21,122        —                   21,122   

Current portion of asset retirement obligations

    3,214        —          696        (a     3,910   
 

 

 

   

 

 

   

 

 

     

 

 

 

Total current liabilities

    216,554        26,564        (25,868       217,250   

NONCURRENT LIABILITIES

         

Long-term debt

    942,726        1,373        348,627        (a     1,292,726   

Asset retirement obligations

    13,917        2,291        1,680        (a     15,597   
        (2,291     (b  

Deferred tax liability

    6,536        2,256        11,544        (a     20,336   

Payable pursuant to tax receivable agreement

    101,678        —          3,486        (a     105,164   

Long-term derivative instruments

    12,465        —                   12,465   

Other noncurrent liabilities

    2        370        (370     (b     2   
 

 

 

   

 

 

   

 

 

     

 

 

 

Total noncurrent liabilities

    1,077,324        6,290     

 

 

 

362,676

 

  

      1,446,290   

 

F-1


    PE Historical     Double Eagle Acquisition     Pro forma adjustments           PE Pro forma  

COMMITMENTS AND CONTINGENCIES

         

Members’ equity

    —          761,282        (761,282     (b     —     

STOCKHOLDERS’ EQUITY

         

Preferred stock

    —          —          —            —     

Common stock:

         

Class A Common Stock

    1,797        —          360        (a     2,157   

Class B Common Stock

    280        —          394        (a     674   

Additional paid in capital

    2,149,388        —          1,589,489        (a     3,738,877   

Accumulated deficit

    (32,510     —          —            (32,510

Treasury stock

    (381     —          —            (381
 

 

 

   

 

 

   

 

 

     

 

 

 

Total stockholders’ equity

    2,118,574        —          1,590,243          3,708,817   

Noncontrolling interest

    344,020        4,517        827,249        (a     1,175,786   
 

 

 

   

 

 

   

 

 

     

 

 

 

Total equity

    2,462,594        765,799        1,656,210          4,884,603   
 

 

 

   

 

 

   

 

 

     

 

 

 

TOTAL LIABILITIES AND EQUITY

    3,756,472        798,653        1,993,018          6,548,143   
 

 

 

   

 

 

   

 

 

     

 

 

 

 

F-2


PARSLEY ENERGY, INC. AND SUBSIDIARIES

PRO FORMA CONSOLIDATED AND COMBINED STATEMENT OF OPERATIONS

FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2016

(in thousands)

 

    PE Historical     Double Eagle
Acquisition
    Pro forma
adjustments
          PE Pro forma  

REVENUES

         

Oil sales

  $ 255,865      $ 19,882      $ —          $ 275,747   

Natural gas sales

    19,834        2,078        —            21,912   

Natural gas liquids sales

    24,811        2,455        —            27,266   

Other

    733        323        —            1,056   
 

 

 

   

 

 

   

 

 

     

 

 

 

Total revenues

    301,243        24,738        —            325,981   
 

 

 

   

 

 

   

 

 

     

 

 

 

OPERATING EXPENSES

         

Lease operating expenses

    44,509        5,739        —            50,248   

Production and ad valorem taxes

    18,993        1,554        —            20,547   

Depreciation, depletion and amortization

    171,113        8,216        (3,586     (c     175,743   

General and administrative expenses

    61,301        7,851        —            69,152   

Exploration costs

    12,779        2,277        —            15,056   

Acquisition costs

    926        —          —            926   

Accretion of asset retirement obligations

    575        65        22          662   

Other operating expenses

    3,767        1,140        —            4,907   
 

 

 

   

 

 

   

 

 

     

 

 

 

Total operating expenses

    313,963        26,842        (3,564       337,241   
 

 

 

   

 

 

   

 

 

     

 

 

 

OPERATING (LOSS) INCOME

    (12,720     (2,104     3,564          (11,260
 

 

 

   

 

 

   

 

 

     

 

 

 

OTHER EXPENSE

         

Interest expense, net

    (38,954     (1,250     (12,531     (d     (52,735

Loss on sale of property

    (119     (2,793     2,793        (g     (119

Loss on derivatives

    (23,842     —          —            (23,842

Other expense

    (950     —          —            (950
 

 

 

   

 

 

   

 

 

     

 

 

 

Total other expense

    (63,865     (4,043     (9,738       (77,646
 

 

 

   

 

 

   

 

 

     

 

 

 

LOSS BEFORE INCOME TAXES

    (76,585     (6,147     (6,174       (88,906

INCOME TAX BENEFIT (EXPENSE)

    21,765        (242     4,315        (e     25,838   
 

 

 

   

 

 

   

 

 

     

 

 

 

NET LOSS

    (54,820     (6,389     (1,859       (63,068
 

 

 

   

 

 

   

 

 

     

 

 

 

LESS: NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS

    11,383        28        6,703        (h     18,114   
 

 

 

   

 

 

   

 

 

     

 

 

 

NET (LOSS) INCOME ATTRIBUTABLE TO PARSLEY ENERGY, INC. STOCKHOLDERS

    (43,437     (6,361     4,844          (44,954
 

 

 

   

 

 

   

 

 

     

 

 

 

Net loss per common share:

         

Basic

  $ (0.28         (f   $ (0.23

Diluted

  $ (0.28         (f   $ (0.23

Weighted average common shares outstanding:

         

Basic

    156,018            (f     192,018   

Diluted

    156,018            (f     192,018   

 

F-3


PARSLEY ENERGY, INC. AND SUBSIDIARIES

PRO FORMA CONSOLIDATED AND COMBINED STATEMENT OF OPERATIONS

FOR THE YEAR ENDED DECEMBER 31, 2015

(in thousands)

 

    PE Historical     Double Eagle
Acquisition
    Pro forma
adjustments
          PE Pro forma  

REVENUES

         

Oil sales

  $ 215,795      $ 8,243      $ —          $ 224,038   

Natural gas sales

    26,582        984        —            27,566   

Natural gas liquids sales

    23,680        872        —            24,552   

Other

    417        (2     —            415   
 

 

 

   

 

 

   

 

 

     

 

 

 

Total revenues

    266,474        10,097        —            276,571   
 

 

 

   

 

 

   

 

 

     

 

 

 

OPERATING EXPENSES

         

Lease operating expenses

    62,913        2,355        —            65,268   

Production and ad valorem taxes

    17,800        685        —            18,485   

Depreciation, depletion and amortization

    178,281        3,622        (1,643     (c     180,260   

General and administrative expenses

    55,294        6,449        —            61,743   

Exploration costs

    13,865        72        —            13,937   

Impairment

    950        —          —            950   

Accretion of asset retirement obligations

    826        5        110          941   

Rig termination costs

    8,970        —          —            8,970   

Other operating expenses

    1,696        384        —            2,080   
 

 

 

   

 

 

   

 

 

     

 

 

 

Total operating expenses

    340,595        13,572        (1,533       352,634   
 

 

 

   

 

 

   

 

 

     

 

 

 

OPERATING (LOSS) INCOME

    (74,121     (3,475     1,533          (76,063
 

 

 

   

 

 

   

 

 

     

 

 

 

OTHER (EXPENSE) INCOME

         

Interest expense, net

    (45,553     (87     (18,288     (d     (63,928

Loss on sale of property

    (34,374     2,498        (2,498     (g     (34,374

Gain on derivatives

    60,818        —          —            60,818   

Other expense

    (3,556     —          —            (3,556
 

 

 

   

 

 

   

 

 

     

 

 

 

Total other (expense) income

    (22,665     2,411        (20,786       (41,040
 

 

 

   

 

 

   

 

 

     

 

 

 

LOSS BEFORE INCOME TAXES

    (96,786     (1,064     (19,253       (117,103

INCOME TAX BENEFIT (EXPENSE)

    23,755        (242     6,086        (e     29,599   
 

 

 

   

 

 

   

 

 

     

 

 

 

NET LOSS

    (73,031     (1,306     (13,167       (87,504
 

 

 

   

 

 

   

 

 

     

 

 

 

LESS: NET LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS

    22,547        —          2,965        (h     25,512   
 

 

 

   

 

 

   

 

 

     

 

 

 

NET LOSS ATTRIBUTABLE TO PARSLEY ENERGY, INC. STOCKHOLDERS

    (50,484     (1,306     (10,202       (61,992
 

 

 

   

 

 

   

 

 

     

 

 

 

Net loss per common share:

         

Basic

  $ (0.45         (f   $ (0.42

Diluted

  $ (0.45         (f   $ (0.42

Weighted average common shares outstanding:

         

Basic

    111,271            (f     147,221   

Diluted

    111,271            (f     147,221   

 

F-4


PARSLEY ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED PRO FORMA CONSOLIDATED AND COMBINED FINANCIAL STATEMENTS

Introduction

Parsley Energy, Inc. (either individually or together with its subsidiaries, as the context requires, “PE” or the “Company”) was formed in December 2013. The Company is the managing member of Parsley Energy, LLC (“Parsley LLC”) and is responsible for all operational, management and administrative decisions of Parsley LLC, and it consolidates the financial results of Parsley LLC and its subsidiaries. The Company is an independent oil and natural gas company focused on the acquisition and development of unconventional oil and natural gas reserves in the Permian Basin. The following unaudited pro forma consolidated and combined financial statements of the Company reflect the consolidated historical results of the Company and the assets acquired in the Double Eagle Acquisition (as defined below), on a pro forma basis to give effect to the following transactions, which are described in further detail below, as if they had occurred on September 30, 2016 for pro forma balance sheet purposes, and on January 1, 2015 and January 1, 2016 for pro forma statements of operations purposes:

The Double Eagle Acquisition . On February 7, 2017, the Company entered into a contribution agreement (the “Double Eagle Contribution Agreement”) with Double Eagle Energy Permian Operating LLC, Double Eagle Energy Permian LLC and Double Eagle Energy Permian Member LLC (collectively, “Double Eagle”), which provides for the contribution by Double Eagle of all of its interests in Double Eagle Lone Star LLC, DE Operating LLC, and Veritas Energy Partners, LLC, as well as certain related transactions with an affiliate of Double Eagle. As a result, the Company expects to acquire (the “Double Eagle Acquisition”) approximately 167,000 gross (71,000 net) acres located in the Midland Basin and approximately 7,300 gross (3,300 net) associated horizontal drilling locations for an aggregate purchase price of approximately $2.8 billion, subject to certain purchase price adjustments set forth in the Double Eagle Contribution Agreement.

The aggregate purchase price for the Double Eagle Acquisition will consist of (i) approximately $1.4 billion in cash and (ii) approximately 39.4 million units in Parsley LLC (“PE Units”) and a corresponding approximately 39.4 million shares of the Company’s Class B common stock (“Class B Common Stock”). Upon the expiration of a 90-day lock-up period following the consummation of the Double Eagle Acquisition, each PE Unit, together with a corresponding share of the Company’s Class B Common Stock, will be exchangeable, at the option of the holder, for one share of the Company’s Class A common stock, or, if either the Company or Parsley LLC so elects, cash.

The Double Eagle Contribution Agreement contains customary representations and warranties, covenants and indemnification provisions and has an effective date of January 1, 2017. The Company and Double Eagle expect to close the Double Eagle Acquisition on or before April 17, 2017, subject to the satisfaction of customary closing conditions.

Equity Offering . For purposes of the unaudited pro forma consolidated and combined financial statements, the “Equity Offering” is defined as the issuance and sale to the public of 36.0 million shares of the Company’s Class A Common stock in February 2017, resulting in approximately $1.1 billion of proceeds, net of underwriting discounts, commissions and offering-related expenses.

2025 Note Offering . For purposes of the unaudited pro forma consolidated and combined financial statements the 2025 Note Offering is defined as the February 2017 issuance of $350.0 million aggregate principal amount of 5.25% senior unsecured notes due 2025 at par (the “2025 Notes Offering” or “2025 Notes”). These notes will be used to partially fund the cost of the proposed Double Eagle Acquisition.

Basis of Presentation. The unaudited pro forma consolidated and combined statements of operations of the Company for the year ended December 31, 2015 are based on the audited historical statements of operations of the Company for the year ended December 31, 2015, adjusted to give effect to the Double Eagle Acquisitions and the aforementioned Equity Offering and 2025 Note Offering as if they occurred on January 1, 2015.

The unaudited pro forma consolidated and combined statements of operations of the Company for the nine months ended September 30, 2016 are based on the unaudited historical statements of operations of the Company for the nine months ended September 30, 2016, adjusted to give effect to the Double Eagle Acquisitions and the aforementioned Equity Offering and 2025 Note Offering as if they occurred on January 1, 2015.

 

F-5


The unaudited pro forma consolidated and combined balance sheet of the Company as of September 30, 2016 is based on the unaudited historical consolidated balance sheet of the Company as of September 30, 2016, adjusted to give effect to the Double Eagle Acquisitions and the aforementioned Equity Offering and Note Offering as if they occurred on September 30, 2016.

The pro forma data presented reflect events directly attributable to the described transactions and certain assumptions that the Company believes are reasonable. The pro forma data are not necessarily indicative of financial results that would have been attained had the described transactions occurred on the dates indicated above because they necessarily exclude various operating expenses, such as incremental general and administrative expenses that may be necessary to run the combined companies. The adjustments are based on currently available information and certain estimates and assumptions. Management believes that the assumptions provide a reasonable basis for presenting the significant effects of the transactions as contemplated and that the pro forma adjustments give appropriate effect to those assumptions and are properly applied in the unaudited pro forma financial statements.

The unaudited pro forma consolidated and combined financial statements and related notes are presented for illustrative purposes only. If the Equity Offering, the Note Offering and the Double Eagle Acquisitions had occurred in the past, the Company’s operating results might have been materially different from those presented in the unaudited pro forma consolidated and combined financial statements. The unaudited pro forma consolidated and combined financial statements should not be relied upon as an indication of operating results that the Company would have achieved if the transactions contemplated herein had taken place on the specified date. In addition, future results may vary significantly from the results reflected in the unaudited pro forma consolidated and combined statements of operations and should not be relied on as an indication of the future results the Company will have after the completion of the transactions noted in these unaudited pro forma consolidated and combined financial statements.

The following notes discuss the columns presented and the entries made to the unaudited consolidated and combined financial statements.

PE Historical . This column represents the unaudited historical statements of operations and consolidated balance sheet for the Company for the applicable period.

Double Eagle Acquisition . This column represents the unaudited historical statements of operations for the assets acquired in the Double Eagle Acquisition for the applicable period.

Note 1. Preliminary Purchase Price Allocation

The purchase price of the Double Eagle Acquisition is estimated at $2.8 billion and is comprised of the fair value of approximately 39.4 million shares of the Company’s Class B Common Stock and approximately 39.4 million associated PE Units issued to the selling shareholders of Double Eagle, with estimated value of $1.4 billion, along with $1.4 billion of cash paid to those same selling shareholders.

The Double Eagle Acquisition will be accounted for using the acquisition method of accounting with the Company as the acquirer. Under the acquisition method of accounting, the Company will record all assets acquired and liabilities assumed at their respective acquisition date fair values, at the closing date of each of the acquisitions. The fair values of the assets acquired and liabilities assumed are based on a detailed analysis, using industry accepted methods of estimating the current fair value as described below.

The Company has further provided an estimate of the fair value of the oil and natural gas properties acquired in the Double Eagle Acquisition. While the Company has not yet undertaken all of the valuation procedures, the Company intends to utilize two valuation methods in its determination of fair value for the oil and natural gas properties, the cash flow analysis and comparable transaction analysis once that acquisition has been closed. The significant assumptions included in the discounted flow analysis include commodity price assumptions, pricing differentials, reserve risking, and discount rates. NYMEX strip

 

F-6


pricing at the acquisition date, less applicable pricing differentials, will be utilized in the discounted cash flow analysis. Risking levels in the discounted cash flow analysis are determined based on a variety of factors, such as; existing well performance, offset production and analogue wells. Discount rates used in the discounted cash flow analysis will be determined by using the estimated weighted average cost of capital for the Company, discount rates published in third party publications, as well as industry knowledge and experience. Comparable transactions will be analyzed to evaluate a range of fair values for similarly situated oil and gas properties that were recently bought or sold in arms-length, observable market transactions. The current preliminary allocation of fair value to the oil and gas properties acquired in the Double Eagle Acquisition is based upon a preliminary discounted cash flow analysis done at the time the purchase and sale agreement was signed and is in a range that is consistent with the anticipated purchase price expected to paid based upon the recent closing price of the Company’s stock.

The preliminary purchase price allocation of the Double Eagle Acquisition is shown below. The final purchase price allocation will be determined when the Company has completed the detail valuations and necessary calculation subsequent to the acquisition. The final purchase price allocation will differ from these estimates and could differ materially from the preliminary allocation used in the pro forma adjustments.

 

    

Preliminary Purchase Price

Allocation

 
     (In thousands)  

Fair value assets acquired:

  

Proved oil and natural gas properties

   $ 140,747   

Unproved oil and natural gas properties

     2,666,623   

Prepayments to operators

     2,031   
  

 

 

 

Total assets acquired

     2,809,401   
  

 

 

 

Fair value of liabilities assumed:

  

Current portion of asset retirement obligations

   $ 696   

Asset retirement obligations

     1,680   

Deferred tax liabilities, net

     7,025   
  

 

 

 

Total liabilities assumed

     9,401   
  

 

 

 

Purchase price of the Double Eagle Acquisition

  

Cash consideration paid

   $ 1,421,964   

Fair value of Class B Common Stock (a)

     1,378,036   
  

 

 

 

Total purchase price

     2,800,000   
  

 

 

 

 

(a)   Based on approximately 39.4 million shares of the Company’s Class B Common stock at an estimated price of $35.00 per share.

Note 2. Pro Forma Adjustments

The Company made the following adjustments in the preparation of the unaudited pro forma financial statements.

 

  (a) Adjustments to reflect the Equity Offering, 2025 Notes Offering and related proceeds

 

    To reflect the increase in cash and cash equivalents of $1.1 billion from the Equity Offering.

 

    To reflect the increase in cash and cash equivalents of $350.0 million from the 2025 Notes Offering.

 

    To reflect the increase in oil and natural gas properties of $2.0 billion related to the Double Eagle Acquisition up to the total amount noted in the purchase price allocations described in Note 1.

 

    To reflect the increase in the current portion of asset retirement obligations of $0.7 million and the long-term portion of asset retirement obligations of $1.7 million related to the Double Eagle Acquisition as noted in the purchase price allocations described in Note 1.

 

    To reflect the $4.2 million increase in deferred tax assets and $11.5 million increase in deferred tax liabilities as a result of remeasurement of taxable basis and the increase in noncontrolling interest percentage.

 

F-7


    The reflect the increase in long term debt of $350.0 million from the 2025 Notes Offering and offset by the elimination of Double Eagle’s prior debt of $1.4 million.

 

    To reflect the $3.5 million increase in the payable pursuant to the tax receivable agreement as a result of remeasurement and the increase in noncontrolling interest percentage.

 

    To reflect the increase in Class A Common Stock of $0.4 million as a result of the Equity Offering.

 

    To reflect the increase in Class B Common Stock of $0.4 million as a result of the issuance of Class B Common Stock.

 

    To reflect the increase in additional paid in capital of $1.6 billion and the increase in noncontrolling interest of $827.2 million as a result of the Equity Offering and the decrease in the Company’s ownership of Parsley LLC. Because the decrease in the Company’s ownership interest in Parsley LLC does not result in a change of control, the transaction is accounted for as an equity transaction under Accounting Standards Codification Topic 810— Consolidation , which requires that any differences between the amount by which the carrying value of the Company’s basis in Parsley LLC is adjusted and the fair value of consideration received are derecognized directly in equity and attributed to the noncontrolling interest. Pro forma for this transaction, the Company’s ownership will have decreased from 86.5% to 76.2% as of September 30, 2016.

 

  (b) Adjustments to reflect the assets and liabilities acquired in the Double Eagle Acquisition.

 

    To reflect the following decrease in cash and cash equivalents of $1.4 billion:

 

    $1.4 billion paid to the owners of Double Eagle

 

    The elimination of $11.3 million of cash owned by Double Eagle that will be retained by the sellers of those entity.

 

    The elimination of $1.5 million of restricted cash owned by Double Eagle that will be retained by the sellers of the entity.

 

    The elimination of $12.8 million of receivables for oil, natural gas and NGLs sales owned by Double Eagle that will be retained by the sellers of the entity.

 

    The elimination of $0.2 million of other current assets owned by Double Eagle that will be retained by the sellers of the entity.

 

    The elimination of $12.4 million of historical accumulated depreciation, depletion, amortization and impairment.

 

    The elimination of $26.2 million of accounts payable and accrued expenses owned by Double Eagle that will be retained by the sellers of the entity.

 

    The elimination of $0.4 million current debt owned by Double Eagle that will be retained by the sellers of the entity.

 

    The elimination of $2.3 million of historical asset retirement obligations as the acquired Double Eagle assets are recorded at fair value.

 

    The elimination of $2.3 million of deferred tax liabilities that will not be transferred to the Company on completion of the Double Eagle Acquisition.

 

F-8


    The elimination of $0.4 million of other noncurrent liabilities owned by Double Eagle that will be retained by the sellers of the entity.

 

    The elimination of $761.3 million of historical members’ equity of Double Eagle.

 

  (c) Adjustments to historical depreciation, depletion, and amortization (“DD&A”) of the assets acquired in the Double Eagle Acquisition for the step up of oil and natural gas properties to estimated fair value. The initial allocation of value was approximately $2.7 billion to unproved property and $0.1 billion to proved property.

 

    To reflect a decrease in DD&A of $3.7 million in the pro forma consolidated and combined statement of operations for the nine months ended September 30, 2016.

 

    This amount includes the elimination of $8.3 million of historical DD&A and is offset by additional DD&A expense of $4.6 million for the nine months ended September 30, 2016.

 

    To reflect a decrease in DD&A of $1.6 million in the pro forma consolidated and combined statement of operations for the year ended December 31, 2015.

 

    This amount includes the elimination of $3.6 million of historical DD&A and is offset by additional DD&A expense of $2.0 million for the year ended December 31, 2015.

 

  (d) Adjustments to reflect the increase in interest expense on approximately $350.0 million of the 2025 Notes. The rate of 5.25% is the interest rate of the 2025 Notes.

 

    To reflect additional interest expense of $12.5 million for the nine months ended September 30, 2016.

 

    This amount includes the elimination of $1.3 million of historical interest expense and is offset by additional interest expense of $13.8 million for the nine months ended September 30, 2016.

 

    To reflect additional interest expense of $18.3 million for the year ended December 31, 2015.

 

  (e) Reflects the estimated incremental income tax provision associated with the Company’s historical results of operations, the results of operations associated with the Double Eagle Acquisition, and pro forma adjustments, assuming these earnings had been subject to federal income tax as a subchapter C corporation using a statutory tax rate of approximately 35.5%, which is inclusive of federal and state income taxes.

 

    To reflect additional income tax benefit of $4.3 million for the nine months ended September 30, 2016.

 

    To reflect additional income tax benefit of $6.1 million for the year ended December 31, 2015.

 

  (f) Basic and diluted earnings per share is based on the sale of 36.0 million shares of the Company’s Class A Common Stock in the Equity Offering and then the issuance of approximately 39.4 million shares of the Company’s Class B Common Stock as consideration in the Double Eagle Acquisition.

 

  (g) Adjustments to reflect the elimination of gain (loss) on sale of Double Eagle assets that will not be purchased by the Company.

 

    To reflect the elimination of a $2.8 million loss on sale of property for the nine months ended September 30, 2016.

 

    To reflect the elimination of a $2.5 million gain on sale of property for the year ended December 31, 2015.

 

F-9


  (h) Reflects the estimated incremental increase in loss attributable to noncontrolling interest holders associated with the Company’s historical results of operations, the results of operations associated with the Double Eagle Acquisition, and pro forma adjustments, assuming these earnings had been subject to the 10.3% increase in noncontrolling interest ownership.

 

    To reflect additional loss attributable to noncontrolling interest owners of $6.7 million for the nine months ended September 30, 2016.

 

    To reflect additional loss attributable to noncontrolling interest owners of $3.0 million for the year ended December 31, 2015.

Note 3. Pro Forma Supplemental Oil and Natural Gas Reserve Information

The following tables set forth certain unaudited pro forma information concerning the Company’s proved oil, natural gas and natural gas liquids (“NGLs”) reserves for the year ended December 31, 2015, giving effect to the Double Eagle Acquisition as if it had occurred on January 1, 2015. There are numerous uncertainties inherent in estimating the quantities of proved reserves and projecting future rates of production and timing of development costs. Further, the volumes considered to be commercially recoverable fluctuate with changes in prices and operating costs. The Company emphasizes that reserve estimates are inherently imprecise and that estimates of new discoveries are more imprecise than those of currently producing oil and natural gas properties. Accordingly, these estimates are expected to change as additional information becomes available in the future. The estimates of reserves, and the standardized measure of future net cash flow, shown below, reflects Double Eagle’s development plan for their properties, rather than the Company’s development plan for the properties. The following reserve data represent estimates only and should not be construed as being precise.

 

     Oil     NGLs     Natural gas     Total  
     (MBbls)     (MBbls)     (MMcf)     Boe  
     PE
Historical
    Double
Eagle
    PE
Historical
    Double
Eagle
    PE
Historical
    Double
Eagle
    PE Pro
forma
 

Proved Developed and Undeveloped Reserves:

  

           

Beginning of the year

     47,617        326        22,667        140        123,645        668        91,469   

Extensions and discoveries

     38,518        4,081        9,232        1,336        53,044        6,750        63,133   

Revisions of previous estimates

     (6,688     32        (6,934     48        (11,825     171        (15,484

Purchases of reserves in place

     1,133        2,435        551        817        4,138        5,418        6,529   

Divestures of reserves in place

     (1,896     —          (278     —          (1,488     —          (2,422

Production

     (4,807     (204     (1,500     (72     (10,339     (456     (8,382
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

End of the year

     73,877        6,670        23,738        2,269        157,175        12,551        134,843   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Proved Developed Reserves:

              

Beginning of the year

     23,547        99        11,491        39        65,484        182        46,120   

End of the year

     27,628        3,779        10,890        1,245        77,612        7,553        57,736   

Proved Undeveloped Reserves:

              

Beginning of the year

     24,070        227        11,175        101        58,161        487        45,348   

End of the year

     46,249        2,890        12,848        1,024        79,563        4,999        77,105   

Standardized Measure of Discounted Future Net Cash Flows

Summarized in the following table is information for the standardized measure of discounted cash flows relating to proved reserves as of December 31, 2015, giving effect to the Double Eagle Acquisition. The standardized measure of discounted future net cash flows does not purport to be, nor should it be interpreted to present, the fair value of the oil and natural gas reserves of the property. An estimate of fair value would take into account, among other things, the recovery of reserves not presently classified as proved, the value of unproved properties, and consideration of expected future economic and operating conditions.

 

F-10


The estimates of future cash flows and future production and development costs as of December 31, 2015 are based on the unweighted arithmetic average first-day-of-the-month price for the preceding 12-month period.

Estimated future production of proved reserves and estimated future production and development costs of proved reserves are based on current costs and economic conditions. All wellhead prices are held flat over the forecast period for all reserve categories. The estimated future net cash flows are then discounted at a rate of 10%.

The standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves is as follows:

 

     December 31, 2015  
     PE Historical      Double Eagle
Acquisition
     PE Pro forma  
     (in thousands)  

Future cash inflows

   $ 4,225,912       $ 378,377         4,604,289   

Future development costs

     (829,560      (67,529      (897,089

Future production costs

     (1,534,011      (135,651      (1,669,662

Future income tax expenses (a)

     (240,203      (731      (240,934
  

 

 

    

 

 

    

 

 

 

Future net cash flows

     1,622,138         174,466         1,796,604   

10% discount to reflect timing of cash flows

     (1,024,290      (91,171      (1,115,461
  

 

 

    

 

 

    

 

 

 

Standardized measure of discounted future net cash flows

   $ 597,848       $ 83,295       $ 681,143   

 

(a) Future net cash flows for Double Eagle do not include the effects of income taxes on future revenues because it is limited liability company not subject to entity-level income taxation. Accordingly, no provision for federal has been provided because taxable income was passed through to their equity holders. Had Double Eagle been subject to entity-level income taxation for federal purposes, it is estimated the additional taxes would be $23.4 million.

In the foregoing determination of future cash inflows, sales prices used for gas and oil for December 31, 2015 were estimated using the average price during the 12-month period, determined as the unweighted arithmetic average of the first-day-of-the-month price for each month. Prices were adjusted by lease for quality, transportation fees and regional price differentials. Future costs of developing and producing the proved gas and oil reserves reported at the end of each year shown were based on costs determined at each such year-end, assuming the continuation of existing economic conditions.

It is not intended that the FASB’s standardized measure of discounted future net cash flows represent the fair market value of the Company’s proved reserves. The Company cautions that the disclosures shown are based on estimates of proved reserve quantities and future production schedules which are inherently imprecise and subject to revision, and the 10% discount rate is arbitrary. In addition, costs and prices as of the measurement date are used in the determinations, and no value may be assigned to probable or possible reserves.

 

F-11


Changes in the standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves are as follows:

 

     December 31, 2015  
     PE Historical      Double Eagle
Acquisition
     PE Pro forma  
     (in thousands)  

Standardized measure of discounted future net cash flows at the beginning of the year

   $ 955,629       $ 8,711       $ 964,340   

Sales of oil and natural gas, net of production costs

     (185,344      (7,097      (192,441

Purchase of minerals in place

     4,872         38,871         43,743   

Divestiture of minerals in place

     (53,018      —           (53,018

Extensions and discoveries, net of future development costs

     485,380         42,328         527,708   

Previously estimated development costs incurred during the period

     12,560         2,421         14,981   

Net changes in prices and production costs

     (821,783      (3,033      (824,816

Changes in estimated future development costs

     77,621         (2,651      74,970   

Revisions of previous quantity estimates

     (225,485      2,897         (222,588

Accretion of discount

     131,442         876         132,318   

Net change in income taxes

     249,065         (309      248,756   

Net changes in timing of production and other

     (33,091      281         (32,810
  

 

 

    

 

 

    

 

 

 

Standardized measure of discounted future net cash flows at the end of the year

   $ 597,848       $ 83,295       $ 681,143   
  

 

 

    

 

 

    

 

 

 

Estimates of economically recoverable oil and natural gas reserves and of future net revenues are based upon a number of variable factors and assumptions, all of which are to some degree subjective and may vary considerably from actual results. Therefore, actual production, revenues, development and operating expenditures may not occur as estimated. The reserve data are estimates only, are subject to many uncertainties and are based on data gained from production histories and on assumptions as to geologic formations and other matters. Actual quantities of oil and natural gas may differ materially from the amounts estimated.

 

F-12

Exhibit 99.8

 

LOGO

February 3, 2017

Ms. Carrie Endorf

Parsley Energy, Inc.

303 Colorado Street, Suite 3000

Austin, Texas 78701

Dear Ms. Endorf:

In accordance with your request, we have audited the estimates prepared by Parsley Energy, Inc. (Parsley), as of December 31, 2016, of the proved reserves and future revenue to the Parsley interest in certain oil and gas properties located in Texas. It is our understanding that the proved reserves estimated herein constitute all of the proved reserves owned by Parsley. We have examined the estimates with respect to reserves quantities, reserves categorization, future producing rates, future net revenue, and the present value of such future net revenue, using the definitions set forth in U.S. Securities and Exchange Commission (SEC) Regulation S-X Rule 4-10(a). The estimates of reserves and future revenue have been prepared in accordance with the definitions and regulations of the SEC and, with the exception of the exclusion of future income taxes, conform to the FASB Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas. We completed our audit on or about the date of this letter. This report has been prepared for Parsley’s use in filing with the SEC; in our opinion the assumptions, data, methods, and procedures used in the preparation of this report are appropriate for such purpose.

The following table sets forth Parsley’s estimates of the net reserves and future net revenue, as of December 31, 2016, for the audited properties:

 

     Net Reserves      Future Net Revenue (M$)  
     Oil      NGL      Gas             Present Worth  

Category

   (MBBL)      (MBBL)      (MMCF)      Total      at 10%  

Proved Developed Producing

     59,255         23,711         121,751         1,666,522         954,438   

Proved Developed Non-Producing

     1,878         596         2,195         54,345         29,080   

Proved Undeveloped

     75,403         24,237         99,659         1,686,435         499,624   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total Proved

     136,536         48,543         223,605         3,407,302         1,483,142   

Totals may not add because of rounding.

The oil volumes shown include crude oil and condensate. Oil and natural gas liquids (NGL) volumes are expressed in thousands of barrels (MBBL); a barrel is equivalent to 42 United States gallons. Gas volumes are expressed in millions of cubic feet (MMCF) at standard temperature and pressure bases.

When compared on a lease-by-lease basis, some of the estimates of Parsley are greater and some are less than the estimates of Netherland, Sewell & Associates, Inc. (NSAI). However, in our opinion the estimates shown herein of Parsley’s reserves and future revenue are reasonable when aggregated at the proved level and have been prepared in accordance with the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers (SPE Standards). Additionally, these estimates are within the recommended 10 percent tolerance threshold set forth in the SPE Standards. We are satisfied with the methods and procedures used by Parsley in preparing the December 31, 2016, estimates of reserves and future revenue, and we saw nothing of an unusual nature that would cause us to take exception with the estimates, in the aggregate, as prepared by Parsley.

 

LOGO


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The estimates shown herein are for proved reserves. Parsley’s estimates do not include probable or possible reserves that may exist for these properties, nor do they include any value for undeveloped acreage beyond those tracts for which undeveloped reserves have been estimated. Reserves categorization conveys the relative degree of certainty; reserves subcategorization is based on development and production status. The estimates of reserves and future revenue included herein have not been adjusted for risk.

Prices used by Parsley are based on the 12-month unweighted arithmetic average of the first-day-of-the-month price for each month in the period January through December 2016. For oil and NGL volumes, the average West Texas Intermediate Phillips 66 posted price of $39.37 per barrel is adjusted for quality, transportation fees, and market differentials. For gas volumes, the average Waha spot price of $2.343 per MMBTU is adjusted for energy content, transportation fees, and market differentials. All prices are held constant throughout the lives of the properties. The average adjusted product prices weighted by production over the remaining lives of the properties are $39.36 per barrel of oil, $15.03 per barrel of NGL, and $2.235 per MCF of gas.

Operating costs used by Parsley are based on historical operating expense records. For the nonoperated properties, these costs include the per-well overhead expenses allowed under joint operating agreements along with estimates of costs to be incurred at and below the district and field levels. Operating costs for the operated properties include direct lease- and field-level costs and $706 per well per month, which is Parsley’s estimate of the portion of its headquarters general and administrative overhead expenses necessary to operate the properties. Operating costs have been divided into per-well costs and per-unit-of-production costs. Capital costs used by Parsley are based on authorizations for expenditure and actual costs from recent activity. Capital costs are included as required for workovers, new development wells, and production equipment. Abandonment costs used are Parsley’s estimates of the costs to abandon the wells and production facilities, net of any salvage value. Operating, capital, and abandonment costs are not escalated for inflation.

The reserves shown in this report are estimates only and should not be construed as exact quantities. Proved reserves are those quantities of oil and gas which, by analysis of engineering and geoscience data, can be estimated with reasonable certainty to be economically producible; probable and possible reserves are those additional reserves which are sequentially less certain to be recovered than proved reserves. Estimates of reserves may increase or decrease as a result of market conditions, future operations, changes in regulations, or actual reservoir performance. In addition to the primary economic assumptions discussed herein, estimates of Parsley and NSAI are based on certain assumptions including, but not limited to, that the properties will be developed consistent with current development plans as provided to us by Parsley, that the properties will be operated in a prudent manner, that no governmental regulations or controls will be put in place that would impact the ability of the interest owner to recover the reserves, and that projections of future production will prove consistent with actual performance. If the reserves are recovered, the revenues therefrom and the costs related thereto could be more or less than the estimated amounts. Because of governmental policies and uncertainties of supply and demand, the sales rates, prices received for the reserves, and costs incurred in recovering such reserves may vary from assumptions made while preparing these estimates.

In the conduct of our audit, we have not independently verified the accuracy and completeness of information and data furnished by Parsley with respect to ownership interests, oil and gas production, well test data, historical costs of operation and development, product prices, or any agreements relating to current and future operations of the properties and sales of production. However, if in the course of our examination something came to our attention that brought into question the validity or sufficiency of any such information or data, we did not rely on such information or data until we had satisfactorily resolved our questions relating thereto or had independently verified such information or data. Our audit did not include a review of Parsley’s overall reserves management processes and practices.

We used standard engineering and geoscience methods, or a combination of methods, including performance analysis and analogy, that we considered to be appropriate and necessary to establish the conclusions set forth herein. As in all aspects of oil and gas evaluation, there are uncertainties inherent in the interpretation of engineering and geoscience data; therefore, our conclusions necessarily represent only informed professional judgment.

 


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engineering and geoscience data; therefore, our conclusions necessarily represent only informed professional judgment.

Supporting data documenting this audit, along with data provided by Parsley, are on file in our office. The technical person primarily responsible for conducting this audit meets the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the SPE Standards. James E. Ball, a Licensed Professional Engineer in the State of Texas, has been practicing consulting petroleum engineering at NSAI since 1998 and has over 17 years of prior industry experience. We are independent petroleum engineers, geologists, geophysicists, and petrophysicists; we do not own an interest in these properties nor are we employed on a contingent basis.

 

Sincerely,
NE THERLAND, SEWELL & ASSOCIATES, INC.
Texas Registered Engineering Firm F-2699
By:  

/s/ C.H. (Scott) Rees III

  C.H. (Scott) Rees III, P.E.
  Chairman and Chief Executive Officer
By:  

/s/ James E. Ball

  James E. Ball, P.E. 57700
  Vice President
Date Signed: February 3, 2017

 

Please be advised that the digital document you are viewing is provided by Netherland, Sewell & Associates, Inc. (NSAI) as a convenience to our clients. The digital document is intended to be substantively the same as the original signed document maintained by NSAI. The digital document is subject to the parameters, limitations, and conditions stated in the original document. In the event of any differences between the digital document and the original document, the original document shall control and supersede the digital document.

 

Exhibit 99.9

E VALUATION

D OUBLE E AGLE E NERGY P ERMIAN LLC I NTERESTS

T OTAL P ROVED R ESERVES

C ERTAIN P ROPERTIES IN T EXAS

A S OF D ECEMBER 31, 2015

 

LOGO


E VALUATION

D OUBLE E AGLE E NERGY P ERMIAN LLC I NTERESTS

T OTAL P ROVED R ESERVES

C ERTAIN P ROPERTIES IN T EXAS

A S OF D ECEMBER 31, 2015

 

C AWLEY , G ILLESPIE  & A SSOCIATES , I NC .

P ETROLEUM CONSULTANTS
Texas Registered Engineering Firm F-693
LOGO


C AWLEY , G ILLESPIE  & A SSOCIATES , I NC .

 

  PETROLEUM CONSULTANTS  
9601 AMBERGLEN BLVD., SUITE 117   306 WEST SEVENTH STREET, SUITE 302   1000 LOUISIANA STREET, SUITE 625
AUSTIN, TEXAS 78729-1106   FORT WORTH, TEXAS 76102-4987   HOUSTON, TEXAS 77002-5008
512-249-7000   817-336-2461   713-651-9944
  www.cgaus.com  

January 30, 2017

Mr. Garrett Martin

Double Eagle Energy Permian, LLC

1401 Ballinger St., Suite 200

Fort Worth, Texas 76102

 

Re:   Evaluation Summary
  Double Eagle Energy Permian LLC Interests
  Total Net Reserves
 

Certain Properties in Texas

As of December 31, 2015

 

Pursuant to the Guidelines of the Securities and Exchange Commission for Reporting Corporate Reserves and Future Net Revenue

Dear Mr. Martin:

As requested, this report was prepared on January 30, 2017 for Double Eagle Energy Permian LLC (“Double Eagle”) for the purpose of submitting our summary level reserve estimates and economic forecasts attributable to the subject interests. We evaluated 100% of the Double Eagle’s reserves, which are located in various oil and gas properties in Texas. This evaluation, effective December 31, 2015, was prepared using constant prices and costs, and conforms to Item 1202(a)(8) of Regulation S-K and other rules of the Securities and Exchange Commission (SEC).

 

                 Proved                       
          Proved      Developed      Proved                
          Developed      Non-      Unde-      Total      Proved  
          Producing      Producing      veloped      Proved      Developed  

Net Reserves

                 

Oil

   – Mbbl      2,927.4         851.6         2,890.1         6,669.1         3,779.0   

Gas

   – MMcf      6,189.7         1,363.2         4,998.7         12,551.6         7,552.9   

NGL

   – Mbbl      982.6         262.0         1,024.3         2,268.9         1,244.6   

Revenue

                 

Oil

   – M$      140,928.8         41,654.2         141,281.4         323,864.4         182,583.0   

Gas

   – M$      14,513.7         2,844.5         10,087.3         27,445.4         17,358.2   

NGL

   – M$      11,962.2         2,971.4         12,134.0         27,067.6         14,933.6   

Severance Taxes

   – M$      8,496.5         2,360.2         8,192.5         19,049.2         10,856.7   

Ad Valorem Taxes

   – M$      4,185.1         1,186.8         4,087.6         9,459.4         5,371.9   

Operating Expenses

   – M$      31,378.1         6,335.6         15,111.7         52,825.4         37,713.7   

Other Deductions

   – M$      34,099.2         4,444.8         15,773.0         54,316.9         38,544.0   

Investments

   – M$      0.0         9,768.5         53,235.2         63,003.7         9,768.5   

Net Operating Income (BFIT)

   – M$      89,245.7         23,374.3         67,102.7         179,722.7         112,620.1   

Discounted at 10%

   – M$      52,985.7         11,201.5         19,820.9         84,008.1         64,187.2   


Double Eagle Energy Permian LLC

January 30, 2017

Page 2

 

Composite forecasts for the Total Proved, Proved Developed, Proved Developed Producing, Proved Developed Non-Producing, and Proved Undeveloped estimates are presented by category in Tables I-TP, I- PD, I-PDP, I-PDNP, and I-PUD, respectively.

Proved Developed (“PD”) reserves are the summation of the Proved Developed Producing and Proved Developed Non-Producing reserve estimates. Proved Developed reserves were estimated at 3,779.0 Mbbl oil, 7,552.9 MMcf gas and 982.6 Mbbl NGLs (or 6,282.4 MBOE). Of the Proved Developed reserves, 4,941.6 MBOE were attributed to producing zones in existing wells and 1,340.8 MBOE were attributed to zones in existing wells not producing. Our estimates are for proved reserves only and do not include any probable or possible reserves nor have any values been attributed to interest in acreage beyond the location for which undeveloped reserves have been estimated.

Future revenue is prior to deducting state production taxes and ad valorem taxes. Future net cash flow is after deducting these taxes, future capital costs and operating expenses, but before consideration of federal income taxes. In accordance with SEC guidelines, the future net cash flow has been discounted at an annual rate of ten percent to determine its “present worth”. The present worth is shown to indicate the effect of time on the value of money and should not be construed as being the fair market value of the properties.

Hydrocarbon Pricing

The base oil and gas prices calculated for December 31, 2015 were $50.28/bbl and $2.587/MMBTU, respectively. As specified by the SEC, a company must use a 12-month average price, calculated as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month period prior to the end of the reporting period. The base oil price is based upon WTI-Cushing spot prices during 2015, and the base gas price is based upon Henry Hub spot prices during 2015.

The base prices were adjusted for differentials on a per-property basis, which may include local basis differentials, transportation, gas shrinkage, gas heating value (BTU content) and/or crude quality and gravity corrections. After these adjustments, the net realized prices for the SEC price case over the life of the proved properties was estimated to be $48.56 per barrel for oil, $2.19 per MCF for gas, and $11.93 per barrel for NGL. All economic factors were held constant in accordance with SEC guidelines.

Economic Parameters

Ownership was accepted as furnished and has not been independently confirmed. Oil and gas price differentials, gas shrinkage, ad valorem taxes, lease operating expenses and investments were calculated and prepared by Double Eagle Energy Permian LLC and were accepted as furnished. Lease operating expenses, price differentials and gas shrinkage were determined at the well level using 12-month averages. Ad valorem tax percentages were determined at the well level by comparing taxes paid to total revenue.

Possible Effects of Federal and State Legislation

Federal, state and local laws and regulations, which are currently in effect and that govern the development and production of oil and natural gas, have been considered in the evaluation of proved reserves for this report. However, the impact of possible changes to legislation or regulations to future


Double Eagle Energy Permian LLC

January 30, 2017

Page 3

 

operating expenses and investment costs have not been included in the evaluation. These possible changes could have an effect on the reserves and economics. However, we do not anticipate nor are we aware of any legislative changes or restrictive regulatory actions that may impact the recovery of reserves.

SEC Conformance and Regulations

The reserve classifications and the economic considerations used herein for the SEC pricing scenario conform to the criteria of the SEC as defined in pages 3 and 4 of the Appendix. The reserves and economics are predicated on regulatory agency classifications, rules, policies, laws, taxes and royalties currently in effect except as noted herein. The possible effects of changes in legislation or other Federal or State restrictive actions which could affect the reserves and economics have not been considered. However, we do not anticipate nor are we aware of any legislative changes or restrictive regulatory actions that may impact the recovery of reserves. If non-commercial PUD properties are shown in Table II’s and individual cash flow tables, they do not meet SEC guidelines for commerciality and therefore are not booked as reserves but are included in this report for the sole purpose of tracking wellbores and/or drilling locations within Double Eagle.

This evaluation includes 104 proved undeveloped locations targeting various formations in the Midland Basin. Each of these drilling locations proposed as part of Double Eagle’s development plans conforms to the proved undeveloped standards as set forth by the SEC. In our opinion, Double Eagle has indicated they have every intent to complete this development plan within the next five years. Furthermore, Double Eagle has demonstrated that they have the proper company staffing, financial backing and prior development success to ensure this five year development plan will be fully executed.

Reserve Estimation Methods

The methods employed in estimating reserves are described in page 2 of the Appendix. Reserves for proved developed producing wells were estimated using production performance methods for the vast majority of properties. Certain new producing properties with very little production history were forecast using a combination of production performance and analogy to offset production, both of which are considered to provide a relatively high degree of accuracy.

Non-producing reserve estimates, for both developed and undeveloped properties, were forecast using either volumetric or analogy methods, or a combination of both. These methods provide a relatively high degree of accuracy for predicting proved developed non-producing and proved undeveloped reserves for Double Eagle Energy Permian LLC properties, due to the mature nature of their properties targeted for development and an abundance of subsurface control data. The assumptions, data, methods and procedures used herein are appropriate for the purpose served by this report.

General Discussion

The estimates and forecasts were based upon interpretations of data furnished by your office and available from our files. All estimates represent our best judgment based on the data available at the time of preparation. Due to inherent uncertainties in future production rates, commodity prices and geologic conditions, it should be realized that the reserve estimates, the reserves actually recovered, the revenue derived therefrom and the actual cost incurred could be more or less than the estimated amounts.


Double Eagle Energy Permian LLC

January 30, 2017

Page 4

 

An on-site field inspection of the properties has not been performed nor have the mechanical operation or condition of the wells and their related facilities been examined nor have the wells been tested by Cawley, Gillespie & Associates, Inc. Possible environmental liability related to the properties has not been investigated or considered nor has the estimated net cost of plugging and the salvage value of equipment at abandonment been included.

Cawley, Gillespie & Associates, Inc. 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. This evaluation was prepared by W. Todd Brooker, P.E., Senior Vice President at Cawley, Gillespie & Associates, Inc. and a State of Texas Licensed Professional Engineer (License #83462). We do not own an interest in the properties or Double Eagle Energy Permian LLC and are not employed on a contingent basis. We have used all methods and procedures that we consider necessary under the circumstances to prepare this report. Our work-papers and related data utilized in the preparation of these estimates are available in our office.

 

   Yours very truly,
   Cawley, Gillespie & Associates, Inc.
   Texas Registered Engineering Firm F-693

LOGO

 

  

LOGO

W. Todd Brooker, P. E.

Senior Vice President


APPENDIX

Explanatory Comments for Summary Tables

 

 

 

 

HEADINGS

Table I

Description of Table Information

Identity of Interest Evaluated

Property Description - Location

Reserve Classification and Development Status

Effective Date of Evaluation

 

FORECAST   
(Columns)   
(1) (11) (21)    Calendar or Fiscal years/months commencing on effective date.
(2) (3) (4)    Gross Production (8/8th) for the years/months which are economical. These are expressed as thousands of barrels (Mbbl) and millions of cubic feet (MMcf) of gas at standard conditions. Total future production, cumulative production to effective date, and ultimate recovery at the effective date are shown following the annual/monthly forecasts.
(5) (6) (7)    Net Production accruable to evaluated interest is calculated by multiplying the revenue interest times the gross production. These values take into account changes in interest and gas shrinkage.
(8)    Average (volume weighted) gross liquid price per barrel before deducting production-severance taxes.
(9)    Average (volume weighted) gross gas price per Mcf before deducting production-severance taxes.
(10)    Average (volume weighted) gross NGL price per barrel before deducting production-severance taxes.
(12)    Revenue derived from oil sales — column (5) times column (8).
(13)    Revenue derived from gas sales — column (6) times column(9).
(14)    Revenue derived from NGL sales — column (7) times column (10).
(15)    Revenue derived from hedge sources.
(16)    Revenue not derived from column (12) through column (15); may include electrical sales revenue and saltwater disposal revenue.
(17)    Total Revenue – sum of column (12) through column(16).
(18)    Production-Severance taxes deducted from gross oil, gas and NGL revenue.
(19)    Ad Valorem taxes .
(20)    $/BOE6 – is the total of column (22), column (25), column (26), and column (27) divided by Barrels of Oil Equivalent (“BOE”). BOE is net oil production column (5) plus net gas production column (6) converted to oil at six Mcf gas per one bbl oil plus net NGL production column (7) converted to oil at one bbl NGL per 0.65 bbls of oil.
(22)    Operating Expenses are direct operating expenses to the evaluated working interest and may include combined fixed rate administrative overhead charges for operated oil and gas producers known as COPAS.
(23)    Average gross wells .
(24)    Average net wells are gross wells times working interest.
(25)    Work-over Expenses are non-direct operating expenses and may include maintenance, well service, compressor, tubing, and pump repair.
(26)    3 rd Party COPAS are combined fixed rate administrative overhead charges for non-operated oil and gas producers.
(27)    Other Deductions may include compression-gathering expenses, transportation costs and water disposal costs.
(28)    Investments , if any, include re-completions, future drilling costs, pumping units, etc. and may include either tangible or intangible or both, and the costs for plugging and the salvage value of equipment at abandonment may be shown as negative investments at end of life.
(29) (30)    Future Net Cash Flow is column (17) less the total of column (18), column (19), column (22), column (25), column (26), column (27), and column (28). The data in column (29) are accumulated in column (30). Federal income taxes have not been considered.
(31)    Cumulative Discounted Cash Flow is calculated by discounting monthly cash flows at the specified annual rates.

MISCELLANEOUS

 

DCF Profile   

•    The cumulative cash flow discounted at six different interest rates are shown at the bottom of columns (30-31). Interest has been compounded monthly. The DCF’s for the “Without Hedge” case may be shown to the left of the main DCF profile.

Life   

•    The economic life of the appraised property is noted in the lower right-hand corner of the table.

Footnotes   

•    Comments regarding the evaluation may be shown in the lower left-hand footnotes.

Price Deck   

•    A table of oil and gas prices, price caps and escalation rates may be shown in the lower middle footnotes.

 

  Cawley, Gillespie & Associates, Inc.   

Appendix

Page 1


APPENDIX

Methods Employed in the Estimation of Reserves

 

 

 

 

The four methods customarily employed in the estimation of reserves are (1)  production performance , (2)  material balance , (3)  volumetric and (4)  analogy . Most estimates, although based primarily on one method, utilize other methods depending on the nature and extent of the data available and the characteristics of the reservoirs.

Basic information includes production, pressure, geological and laboratory data. However, a large variation exists in the quality, quantity and types of information available on individual properties. Operators are generally required by regulatory authorities to file monthly production reports and may be required to measure and report periodically such data as well pressures, gas-oil ratios, well tests,    etc. As a general rule, an operator has complete discretion in obtaining and/or making available geological and engineering data. The resulting lack of uniformity in data renders impossible the application of identical methods to all properties, and may result in significant differences in the accuracy and reliability of estimates.

A brief discussion of each method, its basis, data requirements, applicability and generalization as to its relative degree of accuracy follows:

Production performance . This method employs graphical analyses of production data on the premise that all factors which have controlled the performance to date will continue to control and that historical trends can be extrapolated to predict future performance. The only information required is production history. Capacity production can usually be analyzed from graphs of rates versus time or cumulative production. This procedure is referred to as “decline curve” analysis. Both capacity and restricted production can, in some cases, be analyzed from graphs of producing rate relationships of the various production components. Reserve estimates obtained by this method are generally considered to have a relatively high degree of accuracy with the degree of accuracy increasing as production history accumulates.

Material balance . This method employs the analysis of the relationship of production and pressure performance on the premise that the reservoir volume and its initial hydrocarbon content are fixed and that this initial hydrocarbon volume and recoveries therefrom can be estimated by analyzing changes in pressure with respect to production relationships. This method requires reliable pressure and temperature data, production data, fluid analyses and knowledge of the nature of the reservoir. The material balance method is applicable to all reservoirs, but the time and expense required for its use is dependent on the nature of the reservoir and its fluids. Reserves for depletion type reservoirs can be estimated from graphs of pressures corrected for compressibility versus cumulative production, requiring only data that are usually available. Estimates for other reservoir types require extensive data and involve complex calculations most suited to computer models which makes this method generally applicable only to reservoirs where there is economic justification for its use. Reserve estimates obtained by this method are generally considered to have a degree of accuracy that is directly related to the complexity of the reservoir and the quality and quantity of data available.

Volumetric . This method employs analyses of physical measurements of rock and fluid properties to calculate the volume of hydrocarbons in-place. The data required are well information sufficient to determine reservoir subsurface datum, thickness, storage volume, fluid content and location. The volumetric method is most applicable to reservoirs which are not susceptible to analysis by production performance or material balance methods. These are most commonly newly developed and/or no-pressure depleting reservoirs. The amount of hydrocarbons in-place that can be recovered is not an integral part of the volumetric calculations but is an estimate inferred by other methods and a knowledge of the nature of the reservoir. Reserve estimates obtained by this method are generally considered to have a low degree of accuracy; but the degree of accuracy can be relatively high where rock quality and subsurface control is good and the nature of the reservoir is uncomplicated.

Analogy . This method, which employs experience and judgment to estimate reserves, is based on observations of similar situations and includes consideration of theoretical performance. The analogy method is a common approach used for “resource plays,” where an abundance of wells with similar production profiles facilitates the reliable estimation of future reserves with a relatively high degree of accuracy. The analogy method may also be applicable where the data are insufficient or so inconclusive that reliable reserve estimates cannot be made by other methods. Reserve estimates obtained in this manner are generally considered to have a relatively low degree of accuracy.

Much of the information used in the estimation of reserves is itself arrived at by the use of estimates. These estimates are subject to continuing change as additional information becomes available. Reserve estimates which presently appear to be correct may be found to contain substantial errors as time passes and new information is obtained about well and reservoir performance.

 

  Cawley, Gillespie & Associates, Inc.   

Appendix

Page 2


APPENDIX

Reserve Definitions and Classifications

 

 

 

 

The Securities and Exchange Commission, in SX Reg. 210.4-10 dated November 18, 1981, as amended on September 19, 1989 and January 1, 2010, requires adherence to the following definitions of oil and gas reserves:

“(22) Proved oil and gas reserves . Proved oil and gas reserves are those quantities of oil and 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— prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

“(i) The area of a reservoir considered as proved includes: (A) The area identified by drilling and limited by fluid contacts, if any, and (B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.

“(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.

“(iii) Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty.

“(iv) Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when: (A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and (B) The project has been approved for development by all necessary parties and entities, including governmental entities.

“(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.

“(6) Developed oil and gas reserves . Developed oil and gas reserves are reserves of any category that can be expected to be recovered:

“(i) Through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and

“(ii) Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well.

“(31) Undeveloped oil and gas reserves . Undeveloped oil and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.

“(i) Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances.

“(ii) Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances, justify a longer time.

“(iii) Under no circumstances shall estimates for undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, as defined in paragraph (a)(2) of this section, or by other evidence using reliable technology establishing reasonable certainty.

 

  Cawley, Gillespie & Associates, Inc.   

Appendix

Page 3


“(18) Probable reserves . Probable reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered.

“(i) When deterministic methods are used, it is as likely as not that actual remaining quantities recovered will exceed the sum of estimated proved plus probable reserves. When probabilistic methods are used, there should be at least a 50% probability that the actual quantities recovered will equal or exceed the proved plus probable reserves estimates.

“(ii) Probable reserves may be assigned to areas of a reservoir adjacent to proved reserves where data control or interpretations of available data are less certain, even if the interpreted reservoir continuity of structure or productivity does not meet the reasonable certainty criterion. Probable reserves may be assigned to areas that are structurally higher than the proved area if these areas are in communication with the proved reservoir.

“(iii) Probable reserves estimates also include potential incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than assumed for proved reserves.

“(iv) See also guidelines in paragraphs (17)(iv) and (17)(vi) of this section (below).

“(17) Possible reserves . Possible reserves are those additional reserves that are less certain to be recovered than probable reserves.

“(i) When deterministic methods are used, the total quantities ultimately recovered from a project have a low probability of exceeding proved plus probable plus possible reserves. When probabilistic methods are used, there should be at least a 10% probability that the total quantities ultimately recovered will equal or exceed the proved plus probable plus possible reserves estimates.

“(ii) Possible reserves may be assigned to areas of a reservoir adjacent to probable reserves where data control and interpretations of available data are progressively less certain. Frequently, this will be in areas where geoscience and engineering data are unable to define clearly the area and vertical limits of commercial production from the reservoir by a defined project.

“(iii) Possible reserves also include incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than the recovery quantities assumed for probable reserves.

“(iv) The proved plus probable and proved plus probable plus possible reserves estimates must be based on reasonable alternative technical and commercial interpretations within the reservoir or subject project that are clearly documented, including comparisons to results in successful similar projects.

“(v) Possible reserves may be assigned where geoscience and engineering data identify directly adjacent portions of a reservoir within the same accumulation that may be separated from proved areas by faults with displacement less than formation thickness or other geological discontinuities and that have not been penetrated by a wellbore, and the registrant believes that such adjacent portions are in communication with the known (proved) reservoir. Possible reserves may be assigned to areas that are structurally higher or lower than the proved area if these areas are in communication with the proved reservoir.

“(vi) Pursuant to paragraph (22)(iii) of this section (above), where direct observation has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves should be assigned in the structurally higher portions of the reservoir above the HKO only if the higher contact can be established with reasonable certainty through reliable technology. Portions of the reservoir that do not meet this reasonable certainty criterion may be assigned as probable and possible oil or gas based on reservoir fluid properties and pressure gradient interpretations.”

Instruction 4 of Item 2(b) of Securities and Exchange Commission Regulation S-K was revised January 1, 2010 to state that “a registrant engaged in oil and gas producing activities shall provide the information required by Subpart 1200 of Regulation S–K.” This is relevant in that Instruction 2 to paragraph (a)(2) states: “The registrant is permitted, but not required , to disclose probable or possible reserves pursuant to paragraphs (a)(2)(iv) through (a)(2)(vii) of this Item.”

“(26) Reserves . Reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and gas or related substances to market, and all permits and financing required to implement the project.

“Note to paragraph (26) : Reserves should not be assigned to adjacent reservoirs isolated by major, potentially sealing, faults until those reservoirs are penetrated and evaluated as economically producible. Reserves should not be assigned to areas that are clearly separated from a known accumulation by a non-productive reservoir (i.e., absence of reservoir, structurally low reservoir, or negative test results). Such areas may contain prospective resources (i.e., potentially recoverable resources from undiscovered accumulations).”

 

  Cawley, Gillespie & Associates, Inc.   

Appendix

Page 4

Exhibit 99.10

E VALUATION

D OUBLE E AGLE E NERGY P ERMIAN LLC I NTERESTS

T OTAL P ROVED R ESERVES

C ERTAIN P ROPERTIES IN T EXAS

A S OF D ECEMBER 31, 2014

 

LOGO


E VALUATION

D OUBLE E AGLE E NERGY P ERMIAN LLC I NTERESTS

T OTAL P ROVED R ESERVES

C ERTAIN P ROPERTIES IN T EXAS

A S OF D ECEMBER 31, 2014

 

C AWLEY , G ILLESPIE  & A SSOCIATES , I NC .

P ETROLEUM CONSULTANTS
Texas Registered Engineering Firm F-693
LOGO


C AWLEY , G ILLESPIE  & A SSOCIATES , I NC .

 

  PETROLEUM CONSULTANTS  
9601 AMBERGLEN BLVD., SUITE 117   306 WEST SEVENTH STREET, SUITE 302   1000 LOUISIANA STREET, SUITE 625
AUSTIN, TEXAS 78729-1106   FORT WORTH, TEXAS 76102-4987   HOUSTON, TEXAS 77002-5008
512-249-7000   817-336-2461   713-651-9944
  www.cgaus.com  

January 30, 2017

Mr. Garrett Martin

Double Eagle Energy Permian, LLC

1401 Ballinger St., Suite 200

Fort Worth, Texas 76102

 

Re:   Evaluation Summary
  Double Eagle Energy Permian LLC Interests
  Total Net Reserves
 

Certain Properties in Texas

As of December 31, 2014

 

Pursuant to the Guidelines of the Securities and Exchange Commission for Reporting Corporate Reserves and Future Net Revenue

Dear Mr. Martin:

As requested, this report was prepared on January 30, 2017 for Double Eagle Energy Permian LLC (“Double Eagle”) for the purpose of submitting our summary level reserve estimates and economic forecasts attributable to the subject interests. We evaluated 100% of the Double Eagle’s reserves, which are located in various oil and gas properties in Texas. This evaluation, effective December 31, 2014, was prepared using constant prices and costs, and conforms to Item 1202(a)(8) of Regulation S-K and other rules of the Securities and Exchange Commission (SEC).

 

                 Proved                       
          Proved      Developed      Proved                
          Developed      Non-      Unde-      Total      Proved  
          Producing      Producing      veloped      Proved      Developed  

Net Reserves

                 

Oil

   – Mbbl      78.4         20.3         226.9         325.6         98.7   

Gas

   – MMcf      138.0         43.5         486.8         668.3         181.5   

NGL

   – Mbbl      30.0         9.0         101.1         140.1         39.0   

Revenue

                 

Oil

   – M$      6,559.8         1,713.3         19,174.5         27,447.6         8,273.1   

Gas

   – M$      529.4         155.2         1,736.4         2,420.9         684.5   

NGL

   – M$      854.3         231.7         2,593.0         3,679.1         1,086.0   

Severance Taxes

   – M$      406.3         108.0         1,208.9         1,723.2         514.3   

Ad Valorem Taxes

   – M$      198.6         52.5         587.6         838.7         251.1   

Operating Expenses

   – M$      469.0         59.9         663.3         1,192.2         528.9   

Other Deductions

   – M$      549.4         117.1         1,310.2         1,976.7         666.5   

Investments

   – M$      82.3         163.4         5,169.0         5,414.7         245.7   

Net Operating Income (BFIT)

   – M$      6,237.9         1,599.3         14,564.9         22,402.0         7,837.2   

Discounted at 10%

   – M$      3,274.0         753.1         4,746.1         8,773.2         4,027.1   


Double Eagle Energy Permian LLC

January 30, 2017

Page 2

 

Composite forecasts for the Total Proved, Proved Developed, Proved Developed Producing, Proved Developed Non-Producing, and Proved Undeveloped estimates are presented by category in Tables I-TP, I- PD, I-PDP, I-PDNP, and I-PUD, respectively.

Proved Developed (“PD”) reserves are the summation of the Proved Developed Producing and Proved Developed Non-Producing reserve estimates. Proved Developed reserves were estimated at 98.7 Mbbl oil, 181.5 MMcf gas and 39.0 Mbbl NGLs (or 168.0 MBOE). Of the Proved Developed reserves, 131.4 MBOE were attributed to producing zones in existing wells and 36.6 MBOE were attributed to zones in existing wells not producing. Our estimates are for proved reserves only and do not include any probable or possible reserves nor have any values been attributed to interest in acreage beyond the location for which undeveloped reserves have been estimated.

Future revenue is prior to deducting state production taxes and ad valorem taxes. Future net cash flow is after deducting these taxes, future capital costs and operating expenses, but before consideration of federal income taxes. In accordance with SEC guidelines, the future net cash flow has been discounted at an annual rate of ten percent to determine its “present worth”. The present worth is shown to indicate the effect of time on the value of money and should not be construed as being the fair market value of the properties.

Hydrocarbon Pricing

The base oil and gas prices calculated for December 31, 2014 were $94.99/bbl and $4.35/MMBTU, respectively. As specified by the SEC, a company must use a 12-month average price, calculated as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month period prior to the end of the reporting period. The base oil price is based upon WTI-Cushing spot prices during 2014, and the base gas price is based upon Henry Hub spot prices during 2014.

The base prices were adjusted for differentials on a per-property basis, which may include local basis differentials, transportation, gas shrinkage, gas heating value (BTU content) and/or crude quality and gravity corrections. After these adjustments, the net realized prices for the SEC price case over the life of the proved properties was estimated to be $84.30 per barrel for oil, $3.62 per MCF for gas, and $26.25 per barrel for NGL. All economic factors were held constant in accordance with SEC guidelines.

Economic Parameters

Ownership was accepted as furnished and has not been independently confirmed. Oil and gas price differentials, gas shrinkage, ad valorem taxes, lease operating expenses and investments were calculated and prepared by Double Eagle Energy Permian LLC and were accepted as furnished. Lease operating expenses, price differentials and gas shrinkage were determined at the well level using 12-month averages. Ad valorem tax percentages were determined at the well level by comparing taxes paid to total revenue.

Possible Effects of Federal and State Legislation

Federal, state and local laws and regulations, which are currently in effect and that govern the development and production of oil and natural gas, have been considered in the evaluation of proved reserves for this report. However, the impact of possible changes to legislation or regulations to future


Double Eagle Energy Permian LLC

January 30, 2017

Page 3

 

operating expenses and investment costs have not been included in the evaluation. These possible changes could have an effect on the reserves and economics. However, we do not anticipate nor are we aware of any legislative changes or restrictive regulatory actions that may impact the recovery of reserves.

SEC Conformance and Regulations

The reserve classifications and the economic considerations used herein for the SEC pricing scenario conform to the criteria of the SEC as defined in pages 3 and 4 of the Appendix. The reserves and economics are predicated on regulatory agency classifications, rules, policies, laws, taxes and royalties currently in effect except as noted herein. The possible effects of changes in legislation or other Federal or State restrictive actions which could affect the reserves and economics have not been considered. However, we do not anticipate nor are we aware of any legislative changes or restrictive regulatory actions that may impact the recovery of reserves. If non-commercial PUD properties are shown in Table II’s and individual cash flow tables, they do not meet SEC guidelines for commerciality and therefore are not booked as reserves but are included in this report for the sole purpose of tracking wellbores and/or drilling locations within Double Eagle.

This evaluation includes 24 proved undeveloped locations targeting various formations in the Midland Basin. Each of these drilling locations proposed as part of Double Eagle’s development plans conforms to the proved undeveloped standards as set forth by the SEC. In our opinion, Double Eagle has indicated they have every intent to complete this development plan within the next five years. Furthermore, Double Eagle has demonstrated that they have the proper company staffing, financial backing and prior development success to ensure this five year development plan will be fully executed.

Reserve Estimation Methods

The methods employed in estimating reserves are described in page 2 of the Appendix. Reserves for proved developed producing wells were estimated using production performance methods for the vast majority of properties. Certain new producing properties with very little production history were forecast using a combination of production performance and analogy to offset production, both of which are considered to provide a relatively high degree of accuracy.

Non-producing reserve estimates, for both developed and undeveloped properties, were forecast using either volumetric or analogy methods, or a combination of both. These methods provide a relatively high degree of accuracy for predicting proved developed non-producing and proved undeveloped reserves for Double Eagle Energy Permian LLC properties, due to the mature nature of their properties targeted for development and an abundance of subsurface control data. The assumptions, data, methods and procedures used herein are appropriate for the purpose served by this report.

General Discussion

The estimates and forecasts were based upon interpretations of data furnished by your office and available from our files. All estimates represent our best judgment based on the data available at the time of preparation. Due to inherent uncertainties in future production rates, commodity prices and geologic conditions, it should be realized that the reserve estimates, the reserves actually recovered, the revenue derived therefrom and the actual cost incurred could be more or less than the estimated amounts.


Double Eagle Energy Permian LLC

January 30, 2017

Page 4

 

An on-site field inspection of the properties has not been performed nor have the mechanical operation or condition of the wells and their related facilities been examined nor have the wells been tested by Cawley, Gillespie & Associates, Inc. Possible environmental liability related to the properties has not been investigated or considered nor has the estimated net cost of plugging and the salvage value of equipment at abandonment been included.

Cawley, Gillespie & Associates, Inc. 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. This evaluation was prepared by W. Todd Brooker, P.E., Senior Vice President at Cawley, Gillespie & Associates, Inc. and a State of Texas Licensed Professional Engineer (License #83462). We do not own an interest in the properties or Double Eagle Energy Permian LLC and are not employed on a contingent basis. We have used all methods and procedures that we consider necessary under the circumstances to prepare this report. Our work-papers and related data utilized in the preparation of these estimates are available in our office.

 

   Yours very truly,
   Cawley, Gillespie & Associates, Inc.
   Texas Registered Engineering Firm F-693

LOGO

 

  

LOGO

W. Todd Brooker, P. E.

Senior Vice President


APPENDIX

Explanatory Comments for Summary Tables

 

 

 

 

HEADINGS

Table I

Description of Table Information

Identity of Interest Evaluated

Property Description - Location

Reserve Classification and Development Status

Effective Date of Evaluation

 

FORECAST   
(Columns)   
(1) (11) (21)    Calendar or Fiscal years/months commencing on effective date.
(2) (3) (4)    Gross Production (8/8th) for the years/months which are economical. These are expressed as thousands of barrels (Mbbl) and millions of cubic feet (MMcf) of gas at standard conditions. Total future production, cumulative production to effective date, and ultimate recovery at the effective date are shown following the annual/monthly forecasts.
(5) (6) (7)    Net Production accruable to evaluated interest is calculated by multiplying the revenue interest times the gross production. These values take into account changes in interest and gas shrinkage.
(8)    Average (volume weighted) gross liquid price per barrel before deducting production-severance taxes.
(9)    Average (volume weighted) gross gas price per Mcf before deducting production-severance taxes.
(10)    Average (volume weighted) gross NGL price per barrel before deducting production-severance taxes.
(12)    Revenue derived from oil sales — column (5) times column (8).
(13)    Revenue derived from gas sales — column (6) times column(9).
(14)    Revenue derived from NGL sales — column (7) times column (10).
(15)    Revenue derived from hedge sources.
(16)    Revenue not derived from column (12) through column (15); may include electrical sales revenue and saltwater disposal revenue.
(17)    Total Revenue – sum of column (12) through column(16).
(18)    Production-Severance taxes deducted from gross oil, gas and NGL revenue.
(19)    Ad Valorem taxes .
(20)    $/BOE6 – is the total of column (22), column (25), column (26), and column (27) divided by Barrels of Oil Equivalent (“BOE”). BOE is net oil production column (5) plus net gas production column (6) converted to oil at six Mcf gas per one bbl oil plus net NGL production column (7) converted to oil at one bbl NGL per 0.65 bbls of oil.
(22)    Operating Expenses are direct operating expenses to the evaluated working interest and may include combined fixed rate administrative overhead charges for operated oil and gas producers known as COPAS.
(23)    Average gross wells .
(24)    Average net wells are gross wells times working interest.
(25)    Work-over Expenses are non-direct operating expenses and may include maintenance, well service, compressor, tubing, and pump repair.
(26)    3 rd Party COPAS are combined fixed rate administrative overhead charges for non-operated oil and gas producers.
(27)    Other Deductions may include compression-gathering expenses, transportation costs and water disposal costs.
(28)    Investments , if any, include re-completions, future drilling costs, pumping units, etc. and may include either tangible or intangible or both, and the costs for plugging and the salvage value of equipment at abandonment may be shown as negative investments at end of life.
(29) (30)    Future Net Cash Flow is column (17) less the total of column (18), column (19), column (22), column (25), column (26), column (27), and column (28). The data in column (29) are accumulated in column (30). Federal income taxes have not been considered.
(31)    Cumulative Discounted Cash Flow is calculated by discounting monthly cash flows at the specified annual rates.

MISCELLANEOUS

 

DCF Profile   

•    The cumulative cash flow discounted at six different interest rates are shown at the bottom of columns (30-31). Interest has been compounded monthly. The DCF’s for the “Without Hedge” case may be shown to the left of the main DCF profile.

Life   

•    The economic life of the appraised property is noted in the lower right-hand corner of the table.

Footnotes   

•    Comments regarding the evaluation may be shown in the lower left-hand footnotes.

Price Deck   

•    A table of oil and gas prices, price caps and escalation rates may be shown in the lower middle footnotes.

 

  Cawley, Gillespie & Associates, Inc.   

Appendix

Page 1


APPENDIX

Methods Employed in the Estimation of Reserves

 

 

 

 

The four methods customarily employed in the estimation of reserves are (1)  production performance , (2)  material balance , (3)  volumetric and (4)  analogy . Most estimates, although based primarily on one method, utilize other methods depending on the nature and extent of the data available and the characteristics of the reservoirs.

Basic information includes production, pressure, geological and laboratory data. However, a large variation exists in the quality, quantity and types of information available on individual properties. Operators are generally required by regulatory authorities to file monthly production reports and may be required to measure and report periodically such data as well pressures, gas-oil ratios, well tests, etc. As a general rule, an operator has complete discretion in obtaining and/or making available geological and engineering data. The resulting lack of uniformity in data renders impossible the application of identical methods to all properties, and may result in significant differences in the accuracy and reliability of estimates.

A brief discussion of each method, its basis, data requirements, applicability and generalization as to its relative degree of accuracy follows:

Production performance . This method employs graphical analyses of production data on the premise that all factors which have controlled the performance to date will continue to control and that historical trends can be extrapolated to predict future performance. The only information required is production history. Capacity production can usually be analyzed from graphs of rates versus time or cumulative production. This procedure is referred to as “decline curve” analysis. Both capacity and restricted production can, in some cases, be analyzed from graphs of producing rate relationships of the various production components. Reserve estimates obtained by this method are generally considered to have a relatively high degree of accuracy with the degree of accuracy increasing as production history accumulates.

Material balance . This method employs the analysis of the relationship of production and pressure performance on the premise that the reservoir volume and its initial hydrocarbon content are fixed and that this initial hydrocarbon volume and recoveries therefrom can be estimated by analyzing changes in pressure with respect to production relationships. This method requires reliable pressure and temperature data, production data, fluid analyses and knowledge of the nature of the reservoir. The material balance method is applicable to all reservoirs, but the time and expense required for its use is dependent on the nature of the reservoir and its fluids. Reserves for depletion type reservoirs can be estimated from graphs of pressures corrected for compressibility versus cumulative production, requiring only data that are usually available. Estimates for other reservoir types require extensive data and involve complex calculations most suited to computer models which makes this method generally applicable only to reservoirs where there is economic justification for its use. Reserve estimates obtained by this method are generally considered to have a degree of accuracy that is directly related to the complexity of the reservoir and the quality and quantity of data available.

Volumetric . This method employs analyses of physical measurements of rock and fluid properties to calculate the volume of hydrocarbons in-place. The data required are well information sufficient to determine reservoir subsurface datum, thickness, storage volume, fluid content and location. The volumetric method is most applicable to reservoirs which are not susceptible to analysis by production performance or material balance methods. These are most commonly newly developed and/or no-pressure depleting reservoirs. The amount of hydrocarbons in-place that can be recovered is not an integral part of the volumetric calculations but is an estimate inferred by other methods and a knowledge of the nature of the reservoir. Reserve estimates obtained by this method are generally considered to have a low degree of accuracy; but the degree of accuracy can be relatively high where rock quality and subsurface control is good and the nature of the reservoir is uncomplicated.

Analogy . This method, which employs experience and judgment to estimate reserves, is based on observations of similar situations and includes consideration of theoretical performance. The analogy method is a common approach used for “resource plays,” where an abundance of wells with similar production profiles facilitates the reliable estimation of future reserves with a relatively high degree of accuracy. The analogy method may also be applicable where the data are insufficient or so inconclusive that reliable reserve estimates cannot be made by other methods. Reserve estimates obtained in this manner are generally considered to have a relatively low degree of accuracy.

Much of the information used in the estimation of reserves is itself arrived at by the use of estimates. These estimates are subject to continuing change as additional information becomes available. Reserve estimates which presently appear to be correct may be found to contain substantial errors as time passes and new information is obtained about well and reservoir performance.

 

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APPENDIX

Reserve Definitions and Classifications

 

 

 

 

The Securities and Exchange Commission, in SX Reg. 210.4-10 dated November 18, 1981, as amended on September 19, 1989 and January 1, 2010, requires adherence to the following definitions of oil and gas reserves:

“(22) Proved oil and gas reserves . Proved oil and gas reserves are those quantities of oil and 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— prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

“(i) The area of a reservoir considered as proved includes: (A) The area identified by drilling and limited by fluid contacts, if any, and (B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.

“(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.

“(iii) Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty.

“(iv) Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when: (A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and (B) The project has been approved for development by all necessary parties and entities, including governmental entities.

“(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.

“(6) Developed oil and gas reserves . Developed oil and gas reserves are reserves of any category that can be expected to be recovered:

“(i) Through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and

“(ii) Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well.

“(31) Undeveloped oil and gas reserves . Undeveloped oil and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.

“(i) Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances.

“(ii) Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances, justify a longer time.

“(iii) Under no circumstances shall estimates for undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, as defined in paragraph (a)(2) of this section, or by other evidence using reliable technology establishing reasonable certainty.

 

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“(18) Probable reserves . Probable reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered.

“(i) When deterministic methods are used, it is as likely as not that actual remaining quantities recovered will exceed the sum of estimated proved plus probable reserves. When probabilistic methods are used, there should be at least a 50% probability that the actual quantities recovered will equal or exceed the proved plus probable reserves estimates.

“(ii) Probable reserves may be assigned to areas of a reservoir adjacent to proved reserves where data control or interpretations of available data are less certain, even if the interpreted reservoir continuity of structure or productivity does not meet the reasonable certainty criterion. Probable reserves may be assigned to areas that are structurally higher than the proved area if these areas are in communication with the proved reservoir.

“(iii) Probable reserves estimates also include potential incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than assumed for proved reserves.

“(iv) See also guidelines in paragraphs (17)(iv) and (17)(vi) of this section (below).

“(17) Possible reserves . Possible reserves are those additional reserves that are less certain to be recovered than probable reserves.

“(i) When deterministic methods are used, the total quantities ultimately recovered from a project have a low probability of exceeding proved plus probable plus possible reserves. When probabilistic methods are used, there should be at least a 10% probability that the total quantities ultimately recovered will equal or exceed the proved plus probable plus possible reserves estimates.

“(ii) Possible reserves may be assigned to areas of a reservoir adjacent to probable reserves where data control and interpretations of available data are progressively less certain. Frequently, this will be in areas where geoscience and engineering data are unable to define clearly the area and vertical limits of commercial production from the reservoir by a defined project.

“(iii) Possible reserves also include incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than the recovery quantities assumed for probable reserves.

“(iv) The proved plus probable and proved plus probable plus possible reserves estimates must be based on reasonable alternative technical and commercial interpretations within the reservoir or subject project that are clearly documented, including comparisons to results in successful similar projects.

“(v) Possible reserves may be assigned where geoscience and engineering data identify directly adjacent portions of a reservoir within the same accumulation that may be separated from proved areas by faults with displacement less than formation thickness or other geological discontinuities and that have not been penetrated by a wellbore, and the registrant believes that such adjacent portions are in communication with the known (proved) reservoir. Possible reserves may be assigned to areas that are structurally higher or lower than the proved area if these areas are in communication with the proved reservoir.

“(vi) Pursuant to paragraph (22)(iii) of this section (above), where direct observation has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves should be assigned in the structurally higher portions of the reservoir above the HKO only if the higher contact can be established with reasonable certainty through reliable technology. Portions of the reservoir that do not meet this reasonable certainty criterion may be assigned as probable and possible oil or gas based on reservoir fluid properties and pressure gradient interpretations.”

Instruction 4 of Item 2(b) of Securities and Exchange Commission Regulation S-K was revised January 1, 2010 to state that “a registrant engaged in oil and gas producing activities shall provide the information required by Subpart 1200 of Regulation S–K.” This is relevant in that Instruction 2 to paragraph (a)(2) states: “The registrant is permitted, but not required , to disclose probable or possible reserves pursuant to paragraphs (a)(2)(iv) through (a)(2)(vii) of this Item.”

“(26) Reserves . Reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and gas or related substances to market, and all permits and financing required to implement the project.

“Note to paragraph (26) : Reserves should not be assigned to adjacent reservoirs isolated by major, potentially sealing, faults until those reservoirs are penetrated and evaluated as economically producible. Reserves should not be assigned to areas that are clearly separated from a known accumulation by a non-productive reservoir (i.e., absence of reservoir, structurally low reservoir, or negative test results). Such areas may contain prospective resources (i.e., potentially recoverable resources from undiscovered accumulations).”

 

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