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): September 8,  2016 ( September 6,  2016)

 

 


 

PDC Energy, Inc.

(Exact name of registrant as specified in its charter)

 


 

DELAWARE

 

001-37419

 

95-2636730

(State or other jurisdiction of

 

(Commission

 

(I.R.S. Employer

incorporation or organization)

 

File Number)

 

Identification Number)

 

1775 Sherman Street, Suite 3000

Denver, Colorado 80203

 

Registrant’s telephone number, including area code: 303-860-5800

 


 

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 (see General Instruction A.2. below):

 

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

 

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

 

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

 

o                   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.

 

On September 6, 2016, PDC Energy, Inc. (“we”, “us”, “our”, or the “Company”) entered into that certain Third Amendment and Waiver to Third Amended and Restated Credit Agreement (the “Third Amendment”), which amends that certain Third Amended and Restated Credit Agreement, dated as of May 21, 2013 (as amended from time to time prior to the date hereof, the “Existing Credit Agreement”) among the Company, as Borrower, certain Subsidiaries of the Company, as Guarantors, the lenders from time to time party thereto (the “Lenders”) and JPMorgan Chase Bank, N.A., as Administrative Agent for the Lenders.  The Third Amendment amends the Existing Credit Agreement to, among other things, (i) permit the Company’s recently announced acquisition of properties in the Delaware Basin portion of the Permian Basin region in Texas (the “Acquisition”) and certain financing transactions that the Company may pursue in connection therewith, (ii) effective upon closing of the Acquisition, increase the commitments under the Existing Credit Agreement from $450 million to $700 million and (iii) effective upon closing of the Acquisition, adjust interest rate payable on amounts borrowed under the agreement.

 

The foregoing description of the Third Amendment does not purport to be complete and is qualified in its entirety by reference to the full text of the Third Amendment, which is attached as Exhibit 10.1 to this Current Report on Form 8-K and is incorporated herein by reference.

 

Item 8.01. Other Events.

 

Financial Statements Relating to the Acquisition

 

In August 2016, the Company entered into acquisition agreements to purchase Arris Petroleum Corporation (“Arris”) and the assets of 299 Resources, LLC, 299 Production, LLC and 299 Pipeline, LLC (collectively, “299 Sellers”) pursuant to which, and subject to the terms and conditions of those agreements, the Company has agreed to acquire an aggregate of approximately 57,000 net acres in Reeves and Culberson Counties, Texas, for an aggregate consideration to Arris and 299 Sellers, in the form of cash and stock of the Company, of approximately $1.5 billion, subject to certain adjustments. There can be no assurance such conditions to closing will be satisfied.

 

As the Acquisition is deemed probable and individually significant, in accordance with Rule 3-05 under SEC Regulation S-X, the Company is providing audited and unaudited financial statements and unaudited pro forma financial information in connection with the Acquisition. The audited consolidated financial statements of Arris as of and for the years ended December 31, 2015 and 2014, including the notes and independent auditor’s report related thereto, the unaudited consolidated balance sheet of Arris as of June 30, 2016 and the audited consolidated balance sheet as of December 31, 2015, the unaudited condensed consolidated statements of operations and changes in cash flows of Arris for the six month periods ended June 30, 2016 and 2015 and the unaudited condensed changes in stockholders’ deficit for the six month period ended June 30, 2016, including the notes thereto, are attached as Exhibit 99.1 and incorporated herein by reference. The Company requested and was granted a waiver from the SEC to exclude comparable information for 299 Sellers as the impact of 299 Sellers’ results of operations were insignificant.

 

The unaudited pro forma condensed consolidated balance sheet of the Company as of June 30, 2016, and the unaudited pro forma condensed consolidated statements of operations of the Company for the six months ended June 30, 2016, and for the year ended December 31, 2015, which give effect to the Acquisition, are attached as Exhibit 99.2.

 

Colorado Ballot Initiative Update

 

As discussed in the “Risk Factors” sections of our Annual Report on Form 10-K for the year ended December 31, 2015 and our Quarterly Report on Form 10-Q for the quarter ended June 30, 2016, certain interest groups in Colorado opposed to oil and natural gas development generally, or hydraulic fracturing in particular, have advanced various options for ballot initiatives aimed at significantly limiting or effectively preventing oil and natural gas development in the state of Colorado. On August 29, 2016, the Colorado Secretary of State issued a press release and statements of insufficiency stating that the proponents of two such proposals had failed to collect enough valid signatures to have the proposals included on the ballot for the November 2016 election.

 

One of the initiatives, which we refer to as the “local control” initiative, would have amended the state constitution to give city, town and county governments the right to regulate, or to ban, oil and gas development and

 

2



 

production within their boundaries, notwithstanding rules and approvals to the contrary at the state level.  This proposal was motivated in part by a decision of the Colorado Supreme Court earlier this year holding that local government restrictions on oil and gas activities are subject to preemption by state rules.

 

A second initiative, which we refer to as the “setback” initiative, would have amended the state constitution to require all new oil and gas development facilities to be located at least 2,500 feet away from any occupied structure or “area of special concern,” including public and community drinking water sources, lakes, rivers, perennial or intermittent streams, creeks, irrigation canals, riparian areas, playgrounds, permanent sports fields, amphitheaters, public parks and public open space.

 

If implemented, the setback initiative would have effectively prohibited the vast majority of our planned future drilling activities in Colorado and would therefore have made it impossible to pursue our current development plans. The local control proposal would potentially have had a similar effect, depending on the nature and extent of regulations implemented by relevant local governmental authorities. Pursuant to the determination of the Colorado Secretary of State, these proposals will not appear on the November 2016 ballot.  However, the proponents have 30 days from the date of the Secretary of State’s determination to appeal the decision to the Denver District Court.  If successful, such an appeal could result in either or both proposals being placed on the ballot notwithstanding the Secretary of State’s determination.  Moreover, future proposals of this nature are possible. Because substantially all of our current operations and reserves are located in Colorado, the risks we face with respect to such future proposals are greater than those of our competitors with more geographically diverse operations. Although we cannot predict the outcome of future ballots, statutes or regulatory developments, such developments could materially impact our results of operations, production and reserves.

 

Hedging Update

 

The following table presents our derivative positions related to crude oil and natural gas sales in effect as of September 1, 2016:

 

 

 

Collars

 

Fixed-Price Swaps

 

Basis Protection Swaps

 

 

 

 

 

Quantity
(Gas -

 

 

 

 

 

Quantity
(Gas -

 

Weighted-

 

 

 

Weighted-

 

Fair Value

 

Commodity/ Index/

 

BBtu (1)
Oil -

 

Weighted-Average
Contract Price

 

BBtu (1)
Oil -

 

Average
Contract

 

Quantity

 

Average
Contract

 

September 1,
2016

 

Maturity Period

 

 MBbls)

 

Floors

 

Ceilings

 

 MBbls)

 

Price

 

(BBtu) (1)

 

Price

 

(in millions)

 

Natural Gas

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

NYMEX

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

2016

 

1,200.0

 

$

3.75

 

$

4.04

 

10,490.0

 

$

3.66

 

11,200.0

 

$

(0.27

)

$

7.0

 

2017

 

7,920.0

 

3.59

 

4.13

 

27,290.0

 

3.55

 

12,000.0

 

(0.28

)

15.4

 

2018

 

1,230.0

 

3.00

 

3.67

 

45,280.0

 

2.94

 

16,200.0

 

(0.28

)

(1.8

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Natural Gas

 

10,350.0

 

 

 

 

 

83,060.0

 

 

 

39,400.0

 

 

 

20.6

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Crude Oil

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

NYMEX

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

2016

 

580.0

 

77.59

 

97.55

 

1,240.0

 

72.21

 

 

 

51.0

 

2017

 

1,464.0

 

49.22

 

65.95

 

3,004.0

 

44.92

 

 

 

(3.9

)

2018

 

1,512.0

 

41.85

 

54.31

 

1,512.0

 

51.06

 

 

 

(3.0

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Crude Oil

 

3,556.0

 

 

 

 

 

5,756.0

 

 

 

 

 

 

44.1

 

Total Natural Gas and Crude Oil

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

$

64.7

 

 

3



 


(1)          A standard unit of measurement for natural gas (one BBtu equals one MMcf).

 

Item 9.01. Financial Statements and Exhibits

 

(a) Financial Statements of Business Acquired

 

The audited consolidated financial statements of Arris as of and for the years ended December 31, 2015 and 2014, including the notes and independent auditor’s report related thereto, the unaudited consolidated balance sheet of Arris as of June 30, 2016 and the audited consolidated balance sheet as of December 31, 2015, the unaudited condensed consolidated statements of operations and changes in cash flows of Arris for the six month periods ended June 30, 2016 and 2015 and the unaudited condensed changes in stockholders’ deficit for the six month period ended June 30, 2016, including the notes thereto, are attached as Exhibit 99.1 and incorporated herein by reference.

 

(b) Pro Forma Financial Information

 

The unaudited pro forma condensed consolidated balance sheet of the Company as at June 30, 2016, and the unaudited pro forma condensed consolidated statements of operations of the Company for the six months ended June 30, 2016 and for the year ended December 31, 2015, which give effect to the Acquisition, are attached as Exhibit 99.2.

 

(d) Exhibits

 

See Exhibit Index.

 

4



 

SIGNATURE

 

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: September 8, 2016

 

 

PDC Energy, Inc.

 

 

 

 

By:

/s/ Daniel W. Amidon

 

 

Daniel W. Amidon

 

 

Senior Vice President, General Counsel and Secretary

 

5



 

EXHIBIT INDEX

 

Exhibit
No.

 

Description

 

 

 

10.1

 

Third Amendment to the Third Amended and Restated Credit Agreement, dated as of September 6, 2016, among the Company, as Borrower, certain Subsidiaries of the Company, as Guarantors, the lenders from time to time party thereto (the “Lenders”) and JPMorgan Chase Bank, N.A., as Administrative Agent for the Lenders.

 

 

 

23.1

 

Consent of Independent Auditors, EKS&H LLLP, dated as of September 8, 2016.

 

 

 

23.2

 

Consent of Petroleum Engineer, Cawley, Gillespie & Associates, Inc., dated as of September 8, 2016.

 

 

 

99.1

 

The audited consolidated financial statements of Arris Petroleum Corporation as of and for the years ended December 31, 2015 and 2014, including the notes and independent auditor’s report related thereto, the unaudited consolidated balance sheet of Arris Petroleum Corporation as of June 30, 2016 and the audited consolidated balance sheet as of December 31, 2015, the unaudited condensed consolidated statements of operations and changes in cash flows of Arris Petroleum Corporation for the six month periods ended June 30, 2016 and 2015 and the unaudited condensed changes in stockholders’ deficit for the six month period ended June 30, 2016, including the notes thereto.

 

 

 

99.2

 

The unaudited pro forma condensed consolidated balance sheet of the Company as of June 30, 2016, and the unaudited pro forma condensed consolidated statements of operations of the Company for the six months ended June 30, 2016 and for the year ended December 31, 2015, which give effect to the Acquisition of properties described therein.

 

6


Exhibit 10.1

 

Execution Version

 

THIRD AMENDMENT AND WAIVER TO THIRD AMENDED AND RESTATED

CREDIT AGREEMENT

 

THIRD AMENDMENT AND WAIVER TO THIRD AMENDED AND RESTATED CREDIT AGREEMENT (this “ Amendment ”) is entered into as of September 6, 2016, by and among PDC ENERGY, INC., a Delaware corporation formerly known as Petroleum Development Corporation (the “ Borrower ”), CERTAIN SUBSIDIARIES OF THE BORROWER, as Guarantors (the “ Guarantors ”) , the LENDERS party hereto and JPMORGAN CHASE BANK, N.A., as Administrative Agent (the “ Administrative Agent ”).  Unless the context otherwise requires or unless otherwise expressly defined herein, capitalized terms used but not defined in this Amendment have the meanings assigned to such terms in the Credit Agreement (as defined below) as amended hereby.

 

WITNESSETH:

 

WHEREAS , the Borrower, the Guarantors, the Administrative Agent and the Lenders have entered into that certain Third Amended and Restated Credit Agreement dated as of May 21, 2013 (as the same has been and may hereafter be amended, restated, supplemented or otherwise modified from time to time, the “ Credit Agreement ”);

 

WHEREAS , the Borrower and the Guarantors have requested that the Administrative Agent and the Lenders amend the Credit Agreement in certain respects in order to, among other things, provide for a $250.0 million increase in the Aggregate Commitment thereunder (the “ Incremental Facility ”) and the Administrative Agent and the Lenders constituting the Required Lenders have agreed to do so on the terms and conditions hereinafter set forth.

 

NOW, THEREFORE, for and in consideration of the mutual covenants and agreements herein contained and other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged and confessed, the Borrower, the Guarantors, the Administrative Agent and the Lenders party hereto hereby agree as follows:

 

SECTION 1.                                        Amendments to Credit Agreement.   Subject to the satisfaction or waiver in writing of each applicable condition precedent set forth in Section 3 of this Amendment, and in reliance on the representations, warranties, covenants and agreements contained in this Amendment  to the extent effective as of the Limited Effective Date or the Third Amendment Effective Date, as applicable, the Credit Agreement shall be amended in the manner provided in this Section 1 on the Limited Effective Date and the Third Amendment Effective Date as set forth in Section 3 . For the avoidance of doubt, (a) until an amendment to a Section of the Credit Agreement contemplated herein becomes effective pursuant to Section 3 , such Section shall not be amended hereby and (b) if the conditions set forth in Section 3.2 are not met, the effectiveness of the amendments and waiver that became effective on the Limited Effective Date shall not be affected.

 

1.1                                Amendments to Section 1.01.

 

(a)                                                 Subject to Section 3, the following defined terms are hereby amended and restated in their entirety or added in their entirety, in each case to read as follows:

 

PDC - Third Amendment

 



 

Arris ” means Arris Petroleum Corporation, a Delaware corporation.

 

Asset Purchase Agreement ” means that certain Asset Purchase and Sale Agreement, dated as of August 23, 2016, by and between the Target Asset Sellers, Kimmeridge and the Borrower.

 

Bail-In Action ” means the exercise of any Write-Down and Conversion Powers by the applicable EEA Resolution Authority in respect of any liability of an EEA Financial Institution.

 

Bail-In Legislation ” means, with respect to any EEA Member Country implementing Article 55 of Directive 2014/59/EU of the European Parliament and of the Council of the European Union, the implementing law for such EEA Member Country from time to time which is described in the EU Bail-In Legislation Schedule.

 

Bridge Facility ” means Indebtedness of the Borrower consisting of the Bridge Loans incurred pursuant to the terms of the Bridge Loan Agreement.

 

Bridge Loans ” means loans made pursuant to the Bridge Loan Agreement.

 

Bridge Loan Agreement ” means a bridge loan agreement which may be entered into by and between the Borrower, the Administrative Agent and the lenders from time to time party thereto in an amount not to exceed $600.0 million.

 

Control Agreement ” means a deposit account control agreement or securities account control agreement (or similar agreement), as applicable, in form and substance reasonably satisfactory to the Administrative Agent, executed by the applicable Credit Party, the Administrative Agent and the relevant financial institution party thereto. Such agreement shall provide a first priority perfected Lien in favor of the Administrative Agent, for the benefit of the Secured Parties, in the applicable Credit Party’s Deposit Account and/or Securities Account.

 

Controlled Account ” means a Deposit Account or Securities Account that is subject to a Control Agreement.

 

Deposit Account ” has the meaning assigned to such term in the Uniform Commercial Code of the State of New York or of any other state the laws of which are required to be applied in connection with the perfection of security interests in any Collateral.

 

EEA Financial Institution ” means (a) any institution established in any EEA Member Country which is subject to the supervision of an EEA Resolution Authority, (b) any entity established in an EEA Member Country which is a parent of an institution described in clause (a) of this definition, or (c) any institution established in an EEA Member Country which is a subsidiary of an institution described in clauses (a) or (b) of this definition and is subject to consolidated supervision with its parent.

 

EEA Member Country ” means any of the member states of the European Union, Iceland, Liechtenstein, and Norway.

 

2



 

EEA Resolution Authority ” means any public administrative authority or any Person entrusted with public administrative authority of any EEA Member Country (including any delegee) having responsibility for the resolution of any EEA Financial Institution.

 

EU Bail-In Legislation Schedule ” means the EU Bail-In Legislation Schedule published by the Loan Market Association (or any successor Person), as in effect from time to time.

 

Exchange Notes ” means any Senior Notes received by a lender under the Bridge Loan Agreement in exchange for Bridge Loans outstanding after the Initial Bridge Loan Maturity Date in accordance with the terms of the Bridge Loan Agreement.

 

Initial Bridge Loan Maturity Date ” means the first anniversary of the closing date of the Bridge Facility.

 

Kimmeridge ” means Kimmeridge Energy Management Company GP, LLC, a Delaware limited liability company.

 

Kimmeridge Acquisition ” means, collectively, (a) the Acquisition by the Borrower of Arris and its Subsidiaries pursuant to the Stock Purchase Agreement and (b) the Acquisition by the Borrower of certain assets (collectively, the “ Target Assets ”) owned by the Target Asset Sellers pursuant to the Asset Purchase Agreement.

 

Kimmeridge Acquisition Financing ” means, collectively, the initial financing of the Kimmeridge Acquisition and the refinancing of any interim Indebtedness for the Kimmeridge Acquisition.

 

Offering ” means one or more public or private offerings by the Borrower or its Affiliates of debt securities (including any debt convertible into equity), preferred stock, mandatorily convertible securities, other equity or equity-linked securities or common equity (or any combination thereof) constituting a Kimmeridge Acquisition Financing through (a) the issuance of Senior Notes in a public offering or Rule 144A private placement, (b) the issuance of convertible debt securities in a public offering or Rule 144A private placement and/or (c) the sale of common equity in a public offering.

 

Securities Account ” has the meaning assigned to such term in the Uniform Commercial Code of the State of New York or of any other state the laws of which are required to be applied in connection with the perfection of security interests in any Collateral.

 

Stock Purchase Agreement ” means that certain Stock Purchase and Sale Agreement, dated as of August 23, 2016, by and between the sellers party thereto, Kimmeridge, Arris and the Borrower.

 

Target Assets ” shall have the meaning assigned to such term in the definition of Kimmeridge Acquisition.

 

3



 

Target Asset Sellers ” means, collectively, 299 Resources, LLC, a Delaware limited liability company, 299 Production, LLC, a Delaware limited liability company, and 299 Pipeline, LLC, a Delaware limited liability company.

 

Third Amendment ” means that certain Third Amendment and Waiver to Third Amended and Restated Credit Agreement, dated as of September 6, 2016, between the Borrower, the Guarantors, the Administrative Agent and the Lenders party thereto.

 

Third Amendment Effective Date ” shall have the meaning assigned to such term in the Third Amendment.

 

Write-Down and Conversion Powers ” means, with respect to any EEA Resolution Authority, the write-down and conversion powers of such EEA Resolution Authority from time to time under the Bail-In Legislation for the applicable EEA Member Country, which write-down and conversion powers are described in the EU Bail-In Legislation Schedule.

 

(b)                                                 The definition of “Aggregate Commitment” is hereby amended by (a) replacing the words “Effective Date” with the words “Third Amendment Effective Date” in the last sentence thereof and (b) replacing “$450,000,000” with “$700,000,000” in the last sentence thereof.

 

(c)                                                  The pricing grid contained in the definition of “Applicable Rate” is hereby amended and restated in its entirety to read as follows:

 

Borrowing Base Usage:

 

ABR
Spread

 

Eurodollar
Spread

 

Unused
Commitment Fee
Rate

 

Equal to or greater than 90%

 

2.250

%

3.250

%

0.500

%

Equal to or greater than 75% and less than 90%

 

2.000

%

3.000

%

0.500

%

Equal to or greater than 50% and less than 75%

 

1.750

%

2.750

%

0.500

%

Equal to or greater than 25% and less than 50%

 

1.500

%

2.500

%

0.500

%

Less than 25%

 

1.250

%

2.250

%

0.500

%

 

(d)                                                 The definition of “Defaulting Lender” is hereby amended by (i) deleting the “or” at the end of clause (c) thereof, (ii) replacing the “.” with “, or” at the end of clause (d) thereof and (iii) inserting a new clause (e) to read as follows:

 

(e)                                                  has, or has a Parent that has, become the subject of a Bail-In Action.

 

1.2                                Amendment to Section 2.03.  Section 2.03 of the Credit Agreement is hereby amended and restated in its entirety to read as follows:

 

4



 

Section 2.03.                           Additional Lenders; Increases in the Aggregate Commitment .  If (a) no Default exists as of the date of such increase or would be caused by such increase, (b) the Borrower shall concurrently pay any additional fees required as a result of such increase, (c) immediately after giving effect to such increase, the Aggregate Commitment does not exceed the Borrowing Base then in effect, and (d) at the time of and immediately after giving effect to such increase and any Borrowing made on the date of such increase, the Borrower is in pro forma compliance with the financial covenants set forth in Section 7.11 as of the last day of the most recently ended fiscal quarter for which the financial statements and compliance certificate required under Section 6.01 have been delivered to the Administrative Agent and the Lenders (calculated as though any Borrowing made on the date of such increase had been made as of the last day of such fiscal quarter), the Borrower may, at any time and from time to time, with the consent of the Administrative Agent, increase the Aggregate Commitment to an amount not to exceed the Maximum Facility Amount by providing written notice of such increase to the Administrative Agent, and the Administrative Agent shall promptly notify the Lenders of such increase. To satisfy such requested increase in the Aggregate Commitment, one or more financial institutions reasonably acceptable to the Administrative Agent and the Borrower may elect to participate in such requested increase by executing and delivering to the Borrower and the Administrative Agent, within 30 Business Days of the Administrative Agent’s notice to the Lenders of such requested increase, a certificate substantially in the form of Exhibit F hereto (a “ Lender Certificate ”) and, in the case of a financial institution that is not a Lender, may become a Lender under this Agreement by executing and delivering to the Borrower and the Administrative Agent a Lender Certificate within such 30 Business Day period.  Upon receipt by the Administrative Agent of Lender Certificates representing increases to existing Lender Commitments and/or Commitments from new Lenders as provided in this Section 2.03 in an aggregate amount equal to or greater than the requested increase (as the same may have been adjusted by the Borrower), (i) the Aggregate Commitment (including the Commitment of any Person that becomes a Lender by delivery of such a Lender Certificate) shall be increased on the effective date set forth in such Lender Certificates by the amount indicated in such Lender Certificates or by such lesser amount as necessary such that the Aggregate Commitment is increased only by the amount of the requested increase, with Commitment increases to be allocated among such increasing Lenders in the discretion of the Administrative Agent in consultation with the Borrower, but for the avoidance of doubt, no Lender’s Commitment shall be increased beyond the amount specified in such Lender’s Lender Certificate, (ii) the Register shall be amended to add the Commitment of each additional Lender or to reflect the increase in the Commitment of each existing Lender, and the Applicable Percentages of the Lenders shall be adjusted accordingly to reflect each additional Lender or the increase in the Commitment of each existing Lender, (iii) any such additional Lender shall be deemed to be a party in all respects to this Agreement and any other Loan Documents to which the Lenders are a party, and (iv) upon the effective date set forth in such Lender Certificate, any such Lender party to the Lender Certificate shall purchase and each existing Lender shall assign to such Lender a pro rata portion of the outstanding Credit Exposure of each of the existing Lenders such that the Lenders (including any additional Lender, if applicable) shall have the appropriate portion of the Aggregate Credit Exposure of the Lenders (based in each case on such Lender’s Applicable Percentage, as revised pursuant to this Section), and the Borrower shall have paid to the Lenders any amounts due pursuant to Section 2.16 as a result of such purchase and assignment.

 

5



 

1.3                                Amendment to Section 2.17.   Section 2.17 of the Credit Agreement is hereby amended by inserting a new Subsection 2.17(j) to read as follows:

 

(j)                         FATCA Grandfathering . For purposes of determining withholding Taxes imposed under FATCA, from and after the Third Amendment Effective Date, the Borrower and the Administrative Agent shall treat (and the Lenders hereby authorize the Administrative Agent to treat) this Agreement as not qualifying as a “grandfathered obligation” within the meaning of Treasury Regulation Section 1.1471-2(b)(2)(i).

 

1.4                                Amendment to Article IV.   Article IV of the Credit Agreement is hereby amended by inserting a new Section 4.24 to read as follows:

 

Section 4.24.  EEA Financial Institutions .  No Credit Party is an EEA Financial Institution.

 

1.5                                Amendment to Section 6.09.   Section 6.09 of the Credit Agreement is hereby amended by (a) replacing the word “and” with “,” at the end of Subsection 6.09(e) thereof, (b) replacing “.” with “,” at the end of Subsection 6.09(f) thereof and (c) inserting new Subsections 6.09(g) and (h) to read as follows:

 

(g) pay cash consideration for the Kimmeridge Acquisition (including deposits relating thereto) and (h) pay fees and expenses in connection with the Kimmeridge Acquisition, the Bridge Facility and the Offering.

 

1.6                                Amendment to Section 6.11.   Section 6.11 of the Credit Agreement is hereby amended by replacing each occurrence of “80%” contained therein with “85%”.

 

1.7                                Amendment to Section 6.12.   Section 6.12 of the Credit Agreement is hereby amended by replacing each occurrence of “80%” contained in Subsection 6.12(a) thereof with “85%”.

 

1.8                                Amendment to Section 6.18.  Section 6.18 of the Credit Agreement is hereby amended by inserting a new Subsection 6.18(c) to read as follows:

 

(c)  The Borrower shall use commercially reasonable efforts to grant and perfect Liens in Oil and Gas Interests with Mortgages representing 50% of the Engineered Value of the Direct Interests of Arris and its Subsidiaries and the Target Assets and shall, in any case, grant and perfect such Liens with Mortgages representing 85% of the Engineered Value of the Direct Interests included in the Borrowing Base Properties after giving effect to the Kimmeridge Acquisition no later than January 15, 2017; provided that, notwithstanding anything to the contrary herein, including, without limitation, Sections 6.11 and 6.12 , the Borrower shall not be required to grant and perfect Liens in Oil and Gas Interests of Arris or the Target Assets prior to January 15, 2017.

 

6



 

1.9                                Amendment to Article VI.   Article VI of the Credit Agreement is hereby amended by inserting a new Section 6.20 to read as follows:

 

Section 6.20                  Account Control Agreements . The Borrower will, and will cause each other Credit Party to (a) upon the Administrative Agent’s request, cause each bank or other financial institution in which it maintains a Deposit Account and/or Securities Account to enter into a Control Agreement with the Administrative Agent in order to cause such Deposit Account and/or Securities Account to become a Controlled Account (unless such Deposit Account or Securities Account is already a Controlled Account) and (b) upon the Administrative Agent’s request after the occurrence and during the continuation of an Event of Default, deliver to each such bank or other financial institution a letter, in form and substance acceptable to the Administrative Agent, transferring ownership of the Deposit Account and/or Securities Account to the Administrative Agent until such time as no Event of Default exists. In the event the Borrower or another Credit Party shall establish, hold or maintain any Deposit Account and/or Securities Account not established, held or maintained on or prior to the Limited Effective Date (as defined in the Third Amendment), the Borrower shall promptly notify the Administrative Agent of the existence of such Deposit Account and/or Securities Account.

 

1.10                         Amendments to Section 7.01 .  Section 7.01 of the Credit Agreement is hereby amended by (a) deleting the word “and” at the end of Subsection 7.01(j) thereof, (b) replacing “.” with “;” at the end of Subsection 7.01(k) thereof and (c) inserting new Subsections 7.01(l), (m) and (n) to read as follows:

 

(l) Indebtedness incurred by the Borrower pursuant to the Offering;

 

(m) the Bridge Facility; and

 

(n) the Exchange Notes.

 

1.11                         Amendments to Section 7.04.    Section 7.04 of the Credit Agreement is hereby amended by (a) deleting the word “and” at the end of Subsection 7.04(l) thereof, (b) replacing “.” with “;” at the end of Subsection 7.04(m) thereof and (c) inserting new Subsections 7.04(n) and (o) to read as follows:

 

(n)                      the Kimmeridge Acquisition; and

 

(o)                      any deposits made in connection with any Investment permitted under clauses (e), (j) or (n) of this Section 7.04 .

 

1.12                         Amendment to Section 7.11.   Section 7.11 of the Credit Agreement is hereby amended by replacing “June 30, 2013” with the words “the Third Amendment Effective Date” and replacing “4.25” with “4.00” in Subsection 7.11(b) thereof.

 

1.13                         Amendment to Article XI.   Article XI of the Credit Agreement is hereby amended by inserting a new Section 11.20 to read as follows:

 

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Section 11.20.  Acknowledgement and Consent to Bail-In of EEA Financial Institutions .  Notwithstanding anything to the contrary in any Loan Document or in any other agreement, arrangement or understanding among any such parties, each party hereto acknowledges that any liability of any EEA Financial Institution arising under any Loan Document may be subject to the write-down and conversion powers of an EEA Resolution Authority and agrees and consents to, and acknowledges and agrees to be bound by:

 

(a) the application of any Write-Down and Conversion Powers by an EEA Resolution Authority to any such liabilities arising hereunder which may be payable to it by any party hereto that is an EEA Financial Institution; and

 

(b) the effects of any Bail-In Action on any such liability, including, if applicable:

 

(i) a reduction in full or in part or cancellation of any such liability;

 

(ii) a conversion of all, or a portion of, such liability into shares or other instruments of ownership in such EEA Financial Institution, its parent entity, or a bridge institution that may be issued to it or otherwise conferred on it, and that such shares or other instruments of ownership will be accepted by it in lieu of any rights with respect to any such liability under this Agreement or any other Loan Document; or

 

(iii) the variation of the terms of such liability in connection with the exercise of the Write-Down and Conversion Powers of any EEA Resolution Authority.

 

1.14                         Amendment to Schedules.  Schedule 2.01 of the Credit Agreement is hereby amended by deleting such Schedule in its entirety and replacing it with Schedule 2.01 attached hereto.

 

SECTION 2.                                        Waivers

 

2.1                                Waiver of Borrowing Base Reduction.  The Administrative Agent, acting at the direction of the Required Lenders, hereby waives (such waiver, the “ Borrowing Base Reduction Waiver ”)  the application of Section 3.06 of the Credit Agreement in connection with the Offering and any issuance of Exchange Notes; provided that the waiver contained in this Section 2.1 shall constitute a limited, one-time waiver, and nothing contained herein shall obligate the Lenders to grant any additional or future waiver with respect to, or in connection with, any provision of any Loan Document.

 

2.2                                Call Spread Waiver.   The Administrative Agent, acting at the direction of the Majority Lenders, hereby waives (such waiver, the “ Call Spread Waiver ” and together with the Borrowing Base Reduction Waiver, the “ Waivers ”) (a) compliance by the Borrower with the requirements and limitations set forth in Sections 6.13, 7.01, 7.04, 7.05, 7.06, 7.09, 7.13(a) and 9(g) of the Credit Agreement (in each case, as may be amended by this Amendment) to the extent, and only to the extent that, performance under Permitted New Convertible Notes Swap Agreements would violate such requirements and/or limitations or result in a Default or Event of Default under the Credit Agreement due to the application of such requirements and/or

 

8



 

limitations, (b) compliance by the Borrower with the requirements and limitations set forth in Sections 7.06 and 7.13(a) of the Credit Agreement (in each case, as may be amended by this Amendment) to the extent, and only to the extent that, the issuance of and the performance under the New Convertible Notes by the Borrower would violate such requirements and/or limitations or result in a Default or Event of Default under the Credit Agreement due to the application of such requirements and/or limitations; provided that in the case of this clause (b) cash payments upon conversion of the New Convertible Notes (other than cash in lieu of fractional shares and other than cash payments pursuant to a Permitted Refinancing) may only be made if, immediately after giving effect to such cash payment upon conversion, the Aggregate Commitment exceeds the Aggregate Credit Exposure by 30%, (c) any Default or Event of Default under Section 9(g) of the Credit Agreement resulting from the occurrence of an event or condition under the New Convertible Notes that results in the New Convertible Notes being or becoming convertible at the option of the holder thereof, and (d) any Default or Event of Default that would result from treating Permitted New Convertible Notes Swap Agreements as “Indebtedness” under the Credit Agreement.  Each of the waivers contained in this Section 2.2 shall constitute a limited, one-time waiver, and nothing contained herein shall obligate the Lenders to grant any additional or future waiver with respect to, or in connection with, any provision of any Loan Document. For purposes of this Call Spread Waiver, the following terms shall have the following meanings:

 

New Convertible Notes ” means any convertible debt securities issued by the Borrower pursuant to the Offering.

 

New Convertible Notes Call Options ” means any call options or capped call options purchased by the Borrower from one or more financial institutions relating to the New Convertible Notes and pursuant to which the Borrower is entitled to receive an amount of cash or Equity Interests of the Borrower (or any combination of cash and such Equity Interests) upon conversions of New Convertible Notes from time to time, at maturity of the New Convertible Notes and/or upon termination of such New Convertible Notes Call Options.

 

New Convertible Notes Warrants ” means any warrants to purchase Equity Interests of the Borrower issued to one or more financial institutions substantially contemporaneously with the purchase by the Borrower of New Convertible Notes Call Options from such financial institutions.

 

Permitted New Convertible Notes Swap Agreements ” means each of the New Convertible Notes Call Options and New Convertible Notes Warrants, if any; provided that the aggregate premium payable by the Borrower in connection with the purchase of all such New Convertible Notes Call Options, less the aggregate premium received by the Borrower in connection with the issuance of all such New Convertible Notes Warrants, if any, shall not exceed 20% of the aggregate principal amount of the New Convertible Notes issued pursuant to the Offering.

 

9



 

SECTION 3.                                        Conditions.

 

3.1                                Limited Effective Date.   Each of the amendments to the Credit Agreement contained in Sections 1.1(a) , 1.1(d) , 1.2 , 1.4 , 1.5 , 1.9 , 1.10 , 1.11 , and 1.13 of this Amendment, the Waivers contained in Section 2 of this Amendment and Section 5 of this Amendment shall be effective upon the satisfaction or waiver in writing of each of the following conditions set forth in this Section 3.1 (the date on which each such condition has been satisfied or waived in writing is referred to herein as the “ Limited Effective Date ”):

 

(a)                      Execution and Delivery .   Each Credit Party, the Lenders constituting the Required Lenders, each entity that will become a Lender on the Third Amendment Effective Date (each a “ New Lender ”), each Lender whose Commitment is increased pursuant to Sections 1.1(b)  and 3.2 hereof and the Administrative Agent shall have executed and delivered this Amendment and each other required document, all in form and substance satisfactory to the Administrative Agent.

 

(b)                      No Default .   No Default shall have occurred and be continuing or shall result from the effectiveness of the Amendment.

 

(c)                       Representations and Warranties. After giving effect to the amendments and waivers contained in the Sections of this Amendment specified above in this Section 3.1 , each representation and warranty of the Credit Parties contained in the Credit Agreement and in each of the other Loan Documents is true and correct in all material respects on the Limited Effective Date (except to the extent such representations and warranties relate solely to an earlier date, in which case they are true and correct in all material respects as of such earlier date).

 

(d)                      Officer’s Certificates. The Administrative Agent shall have received (i) a certificate from the principal financial officer of the Borrower, in form and substance reasonably acceptable to the Administrative Agent, certifying that the Borrower and its Restricted Subsidiaries, taken as a whole, after giving effect to the transactions contemplated hereby to occur on or prior to the Limited Effective Date, are Solvent and (ii) a customary closing certificate from a Responsible Officer of the Borrower in form and substance reasonably satisfactory to the Administrative Agent.

 

3.2                                Third Amendment Effective Date.   Each of the amendments to the Credit Agreement contained in Sections 1.1(b) , 1.1(c) , 1.3 , 1.6 , 1.7 , 1.8 , 1.12 and 1.14 of this Amendment and Section 4 of this Amendment shall be effective upon the satisfaction or waiver in writing of each of the following conditions set forth in this Section 3.2 (the date on which each such condition has been satisfied or waived in writing is referred to herein as the “ Third Amendment Effective Date ”); provided that the Third Amendment Effective Date occurs on or prior to December 31, 2016; provided further that if the Purchase Agreements are amended solely to extend their respective termination dates, this date may be extended to the termination date set forth in such amendments, but in no case shall this date be extended beyond January 15, 2017:

 

(a)                      Limited Effective Date. The Limited Effective Date shall have occurred.

 

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(b)                      Legal Opinions .   The Administrative Agent shall have received an opinion by Davis Graham & Stubbs LLP, as counsel to the Credit Parties, in a form reasonably satisfactory to the Administrative Agent.

 

(c)                       Officer’s Certificates. The Administrative Agent shall have received (i) a certificate from the principal financial officer of the Borrower, in form and substance reasonably acceptable to the Administrative Agent, certifying that the Borrower and its Restricted Subsidiaries, taken as a whole, after giving effect to the transactions contemplated hereby, are Solvent and (ii) a customary closing certificate from a Responsible Officer of the Borrower in form and substance reasonably satisfactory to the Administrative Agent.

 

(d)                      Minimum Gross Cash Proceeds.   The Borrower shall have received $600.0 million in aggregate gross cash proceeds from (i) the Offering, (ii) the Bridge Facility and/or (iii) any asset sales for cash between August 23, 2016 and the Third Amendment Effective Date exceeding, individually or in the aggregate, $5.0 million.

 

(e)                       Equity Issuance.   As partial consideration for the Kimmeridge Acquisition, the Borrower shall have issued the amount of equity contemplated to be issued by it under the Stock Purchase Agreement, Asset Purchase Agreement and those certain Investment Agreements entered into simultaneously with the closings of the transactions contemplated by the Asset Purchase Agreement and Stock Purchase Agreement, by and between the Borrower and the Investors (as defined in each Investment Agreement) party thereto (the “ Investment Agreements ”).

 

(f)                        No Other Indebtedness. After giving effect to this Amendment, the Kimmeridge Acquisition, the Bridge Facility and the Offering, neither the Borrower nor any of its Subsidiaries shall have any material Indebtedness for borrowed money other than (i) the Obligations, (ii) the Bridge Facility (or any securities constituting Indebtedness issued pursuant to the Offering in lieu of the Bridge Facility), (iii) Indebtedness permitted under Section 7.01 of the Credit Agreement (as amended hereby), (iv) the Original Senior Notes and (v) the Convertible Notes.

 

(g)                       Kimmeridge Acquisition.  The consummation of the Kimmeridge Acquisition pursuant to the terms of the Stock Purchase Agreement and the Asset Purchase Agreement (together, the “ Purchase Agreements ”) shall be a concurrent condition to the Third Amendment Effective Date, and no provision of either Purchase Agreement shall have been amended or waived, and no consent shall have been given thereunder by the Borrower or its Affiliates in any manner materially adverse to the interests of the Administrative Agent or the Lenders without the prior written consent of the Administrative Agent, not to be unreasonably withheld, conditioned or delayed (it being understood that (i) any amendment to the definition of “Company Material Adverse Effect” in the Stock Purchase Agreement (as in effect on the date thereof) or “Seller Material Adverse Effect” in the Asset Purchase Agreement (as in effect on the date thereof) shall be deemed material and adverse to the interests of the Administrative Agent and Lenders and (ii) any increase or decrease in the purchase price in respect of the Kimmeridge Acquisition pursuant to any purchase price or similar adjustment provisions (including with respect to New

 

11



 

Leases (as defined in the Purchase Agreements), title defects, environmental defects, required consents, preferential purchase rights, and uncured casualty losses) set forth in the Purchase Agreements (as in effect on the date thereof) shall not constitute an alteration, amendment, change, supplement, waiver, consent or other modification to the Purchase Agreements, and shall not be deemed to be materially adverse to the interests of the Administrative Agent and Lenders, unless and until the aggregate value of such adjustments would cause Borrower’s closing condition set forth in Section 7.2(f) of the Asset Purchase Agreement and Section 7.2(g) of the Stock Purchase Agreement not to be satisfied).

 

(h)                      Production and Accounting Statements. The Administrative Agent shall have received such production and monthly accounting statements with respect to the Target Assets that are received by the Borrower pursuant to the Asset Purchase Agreement.

 

(i)                          Audited Financial Statements; Other Reports. The Administrative Agent shall have received (i) audited consolidated balance sheets and related statements of income, stockholders’ equity and cash flows of the Borrower and its Subsidiaries, for the three most recently completed fiscal years ended at least 90 days before the Third Amendment Effective Date, (ii) unaudited consolidated balance sheets and related statements of income, stockholders’ equity and cash flows of the Borrower and its Subsidiaries, for each subsequent fiscal quarter (other than the fourth fiscal quarter of any fiscal year) ended at least 45 days before the Third Amendment Effective Date (in each case, together with the corresponding comparative period from the prior fiscal year), (iii) audited consolidated balance sheets and related statements of income, stockholders’ equity and cash flows of Arris for the two most recently completed fiscal years ended at least 90 days before the Third Amendment Effective Date, (iv) unaudited consolidated balance sheets and related statements of income, stockholders’ equity and cash flows of Arris, for each subsequent fiscal quarter (other than the fourth fiscal quarter of any fiscal year) ended at least 45 days before the Third Amendment Effective Date (in each case, together with the corresponding comparative period from the prior fiscal year), (v) with respect to the Target Assets, such financial statements to the extent required for a shelf takedown from Borrower’s existing registration statement on Form S-3 under the Securities Act, and (vi) the reserve reports for the proved oil and gas properties of the Borrower and its Subsidiaries and, to the extent required for a shelf takedown from Borrower’s existing registration statement on Form S-3 under the Securities Act, Arris and the Target Assets, in each case for the most recently completed fiscal year ended at least 90 days before the Third Amendment Effective Date (which reports shall be prepared according to SEC guidelines by one or more reputable third party engineers); provided that filing of the required financial statements in clauses (i) and (ii) above on form 10-K and form 10-Q by the Borrower with the Securities and Exchange Commission through the “Electronic Data Gathering, Analysis and Retrieval” system will satisfy the foregoing requirements.

 

(j)                         Pro Forma Financial Statements. The Administrative Agent shall have received a pro forma consolidated balance sheet and related pro forma consolidated statement of income of the Borrower and its Subsidiaries as of and for the twelve-month period ending on the last day of the most recently completed four-fiscal quarter period ended at least 45 days prior to the Third Amendment Effective Date, in each case, prepared in accordance with Regulation S-X after

 

12



 

giving effect to each of the Kimmeridge Acquisition, the Offering, this Amendment and the closing of the Bridge Facility as if the Kimmeridge Acquisition, the Offering, this Amendment and the closing of the Bridge Facility had occurred as of such date (in the case of such balance sheet) or at the beginning of such period (in the case of such statement of income), in each case to the extent necessary for a shelf takedown from Borrower’s existing registration statement on Form S-3 under the Securities Act.

 

(k)                      Fees .  The Administrative Agent shall have received, for its own account and for the account of the Lenders, the fees separately agreed upon in the fee letter executed by the Borrower and the Administrative Agent on August 23, 2016.

 

(l)                          First Priority Liens; Mortgages . (i) All actions necessary to establish that the Administrative Agent will have a perfected first priority Lien (subject to Liens permitted under the Credit Agreement as amended hereby) in the Collateral under the Credit Agreement shall have been taken, including, without limitation, a Mortgage Lien (and receipt of title information) on 85% of the Engineered Value of the Direct Interests included in the Borrowing Base Properties (prior to giving effect to the Kimmeridge Acquisition); provided that, to the extent any Collateral (including the grant or perfection of any security interest) is not or cannot be provided on the Third Amendment Effective Date (other than the grant and perfection of liens (x) in assets with respect to which a lien may be perfected solely by the filing of a financing statement under the Uniform Commercial Code, (y) in capital stock with respect to which a lien may be perfected by the delivery of a stock certificate or (z) the Mortgage Liens referred to above in this clause (i)), after the Borrower’s use of commercially reasonable efforts to do so without undue burden or expense, then the provision of such Collateral shall not constitute a condition precedent to the Third Amendment Effective Date, but shall instead be provided within thirty (30) days of the Third Amendment Effective Date, subject to the application of Section 6.18(c) of the Credit Agreement as amended hereby (such proviso being referred to herein as the “ Limited Conditionality Provision ”) and (ii) (x) all prior material Indebtedness for borrowed money secured by a Lien in the Target Assets (other than Indebtedness permitted under the Credit Agreement as amended hereby) shall have been paid, redeemed, defeased and discharged in full, (y) the Administrative Agent shall have received a customary payoff letter in connection with the same, and (z) all prior Liens in the Target Assets (other than Liens permitted under the Credit Agreement as amended hereby) shall have been released.

 

(m)                  PATRIOT Act. The Administrative Agent shall have received, at least 3 days prior to the Third Amendment Effective Date, to the extent requested by the Administrative Agent or its counsel at least 10 days prior to the Third Amendment Effective Date, all documentation and other information required by regulatory authorities under applicable “know your customer” and anti-money laundering rules and regulations, including the PATRIOT Act.

 

(n)                      Representations and Warranties.   After giving effect to the amendments contained herein, each representation and warranty of (i) Arris contained in the Stock Purchase Agreement (as in effect on August 23, 2016) that is material to the interests of the Lenders, but only to the extent the accuracy of any such representation is a condition to the obligation of the Borrower (or an Affiliate thereof) to close under the Stock Purchase Agreement, or the Borrower

 

13



 

(or an Affiliate thereof) has the right to terminate the Stock Purchase Agreement as a result of a breach of such representation, (ii) the Target Asset Sellers contained in the Asset Purchase Agreement (as in effect on August 23, 2016) that is material to the interests of the Lenders, but only to the extent the accuracy of any such representation is a condition to the obligation of the Borrower (or an Affiliate thereof) to close under the Asset Purchase Agreement, or the Borrower (or an Affiliate thereof) has the right to terminate the Asset Purchase Agreement as a result of a breach of such representation and (iii) such Credit Party contained in Sections 4.01 , 4.02 , 4.03 (except to the extent such conflict has not resulted in a Company Material Adverse Effect (as defined in the Stock Purchase Agreement (as in effect on August 23, 2016)) or a Seller Material Adverse Effect (as defined in the Asset Purchase Agreement (as in effect on August 23, 2016))), 4.07 , 4.08 , 4.14 , 4.17 , 4.21 (subject to the application of the Limited Conditionality Provision), 4.22 , and 4.23 of the Credit Agreement shall be true and correct in all material respects on the Third Amendment Effective Date (except to the extent such representations and warranties relate solely to an earlier date, in which case they are true and correct in all material respects as of such earlier date).

 

SECTION 4.                                        Representations and Warranties of Credit Parties .   To induce the Lenders to enter into this Amendment, each Credit Party hereby represents and warrants to the Lenders as follows:

 

4.1                                Corporate Authority; No Conflicts .   The execution, delivery and performance by such Credit Party of this Amendment and all documents, instruments and agreements contemplated herein are within such Credit Party’s corporate or other organizational powers, have been duly authorized by necessary action, require no action by or in respect of, or filing with, any court or agency of government and do not violate or constitute a default under any provision of any applicable law or other agreements binding upon such Credit Party or result in the creation or imposition of any Lien upon any of the assets of such Credit Party.

 

4.2                                Enforceability .   This Amendment constitutes the valid and binding obligation of such Credit Party enforceable in accordance with its terms, except as (i) the enforceability thereof may be limited by bankruptcy, insolvency or similar laws affecting creditor’s rights generally, and (ii) the availability of equitable remedies may be limited by equitable principles of general application.

 

4.3                                No Default .   As of the date hereof, both before and immediately after giving effect to this Amendment, no Default or Event of Default has occurred and is continuing.

 

SECTION 5.                                        Miscellaneous .

 

5.1                                Reaffirmation of Loan Documents and Liens .   Any and all of the terms and provisions of the Credit Agreement and the other Loan Documents shall, except as amended and modified hereby, remain in full force and effect and are hereby in all respects ratified and confirmed by each Credit Party.  Each Credit Party hereby agrees that the amendments and modifications herein contained shall in no manner affect or impair the liabilities, duties and

 

14



 

obligations of any Credit Party under the Credit Agreement and the other Loan Documents or the Liens securing the payment and performance thereof.

 

5.2                                Parties in Interest .   All of the terms and provisions of this Amendment shall bind and inure to the benefit of the parties hereto and their respective successors and assigns.

 

5.3                                Legal Expenses.   Each Credit Party hereby agrees to pay all reasonable fees and expenses of counsel to the Administrative Agent incurred by the Administrative Agent in connection with the preparation, negotiation and execution of this Amendment and all related documents.

 

5.4                                Request for Account Control Agreements.   The Administrative Agent hereby requests that the Borrower cause, and cause each other Credit Party to cause, each Deposit Account and/or Securities Account established, held or maintained by the Borrower or such other Credit Party on or prior to the Third Amendment Effective Date to become a Controlled Account no later than the Third Amendment Effective Date in accordance with Section 6.20 of the Credit Agreement as amended hereby.

 

5.5                                Counterparts .   This Amendment may be executed in one or more counterparts and by different parties hereto in separate counterparts each of which when so executed and delivered shall be deemed an original, but all such counterparts together shall constitute but one and the same instrument; signature pages may be detached from multiple separate counterparts and attached to a single counterpart so that all signature pages are physically attached to the same document.  Delivery of photocopies of the signature pages to this Amendment by facsimile or electronic mail shall be effective as delivery of manually executed counterparts of this Amendment.

 

5.6                                Complete Agreement .   THIS AMENDMENT, THE CREDIT AGREEMENT, AND THE OTHER LOAN DOCUMENTS REPRESENT THE FINAL AGREEMENT BETWEEN THE PARTIES AND MAY NOT BE CONTRADICTED BY EVIDENCE OF PRIOR, CONTEMPORANEOUS OR ORAL AGREEMENTS OF THE PARTIES.  THERE ARE NO UNWRITTEN ORAL AGREEMENTS AMONG THE PARTIES.

 

5.7                                Headings .   The headings, captions and arrangements used in this Amendment are, unless specified otherwise, for convenience only and shall not be deemed to limit, amplify or modify the terms of this Amendment, nor affect the meaning thereof.

 

5.8                                Governing Law.   This Amendment shall be construed in accordance with and governed by the law of the State of New York without regard to conflicts of law.

 

5.9                                New Lenders.   Each New Lender shall execute a Lender Certificate to evidence the Commitments of such New Lender which Lender Certificate will be effective, and such New Lender shall be deemed to be a Lender in all respects under the Credit Agreement and the other Loan Documents, concurrently with the satisfaction of the conditions set forth in Section 3.2 hereto on the Third Amendment Effective Date.

 

15



 

[Remainder of Page Intentionally Blank.  Signature Pages Follow.]

 

16



 

IN WITNESS WHEREOF, the parties have caused this Amendment to be duly executed as of the date first above written.

 

 

BORROWER:

 

 

 

PDC ENERGY, INC.

 

 

 

 

 

By:

/s/ Barton R. Brookman, Jr.

 

Name: Barton R. Brookman, Jr.

 

Title: President and Chief Executive Officer

 

 

 

GUARANTORS:

 

 

 

RILEY NATURAL GAS COMPANY

 

 

 

 

 

By:

/s/ Lance A. Lauck

 

Name: Lance A. Lauck

 

Title: President

 

Signature Page

 



 

 

JPMORGAN CHASE BANK, N.A ., as

 

Administrative Agent, Issuing Bank and as a Lender

 

 

 

 

 

By:

/s/ Jo Linda Papadakis

 

Name: Jo Linda Papadakis

 

Title: Authorized Officer

 

Signature Page

 



 

 

BANK OF AMERICA, N.A., as a Lender

 

 

 

 

 

By:

/s/ Ronald E. McKaig

 

Name: Ronald E. McKaig

 

Title: Managing Director

 

Signature Page

 



 

 

BANK OF MONTREAL, as a Lender

 

 

 

 

 

By:

/s/ Gumaro Tijerina

 

Name: Gumaro Tijerina

 

Title: Managing Director

 

Signature Page

 



 

 

COMPASS BANK , as a Lender

 

 

 

 

 

By:

/s/ Kathleen J. Bowen

 

Name: Kathleen J. Bowen

 

Title: Managing Director

 

Signature Page

 



 

 

CREDIT AGRICOLE CORPORATE AND
INVESTMENT BANK,
as a Lender

 

 

 

 

 

By:

/s/ Michael D. Willis

 

 

Name: Michael D. Willis

 

 

Title: Managing Director

 

 

 

 

 

 

 

By:

/s/ Darrell Stanley

 

 

Name: Darrell Stanley

 

 

Title: Managing Director

 

Signature Page

 



 

 

THE BANK OF NOVA SCOTIA, as a Lender

 

 

 

 

 

By:

/s/ Alan Dawson

 

Name: Alan Dawson

 

Title: Director

 

Signature Page

 



 

 

SCOTIABANC INC. ,

 

as a Lender

 

 

 

 

 

By:

/s/ K. Zhou

 

Name: K. Zhou

 

Title: Director

 

Signature Page

 



 

 

WELLS FARGO BANK, N.A. ,

 

as a Lender

 

 

 

 

 

By:

/s/ Dalton Harris

 

Name: Dalton Harris

 

Title: Vice President

 

Signature Page

 



 

 

BOKF, NA d/b/a BANK OF OKLAHOMA,

 

as a Lender

 

 

 

 

 

By:

/s/ Eric Griffin

 

Name: Eric Griffin

 

Title: Senior Vice President

 

Signature Page

 



 

 

CAPITAL ONE, NATIONAL ASSOCIATION,

 

as a Lender

 

 

 

 

 

By:

/s/ Kristin N. Oswald

 

Name: Kristin N. Oswald

 

Title: Vice President

 

Signature Page

 



 

 

COMERICA BANK ,

 

as a Lender

 

 

 

 

 

By:

/s/ Garrett R. Merrell

 

Name: Garrett R. Merrell

 

Title: Relationship Manager

 

Signature Page

 



 

 

NATIXIS , NEW YORK BRANCH,

 

as a Lender

 

 

 

 

 

By:

/s/ Timothy Polvado

 

Name: Timothy Polvado

 

Title: Senior Managing Director

 

 

 

 

 

By:

/s/ Leila Zomorrodian

 

Name: Leila Zomorrodian

 

Title: Director

 

Signature Page

 



 

 

TEXAS CAPITAL BANK, N.A. ,

 

as a Lender

 

 

 

 

 

By:

/s/ Gabriela A. Ramirez

 

Name: Gabriela A. Ramirez

 

Title: Vice President

 

Signature Page

 



 

 

U.S. BANK NATIONAL ASSOCIATION ,

 

as a Lender

 

 

 

 

 

By:

/s/ Tara McLean

 

Name: Tara McLean

 

Title: Vice President

 

Signature Page

 



 

 

KEYBANK NATIONAL ASSOCIATION,

 

as a Lender

 

 

 

 

 

By:

/s/ George McKean

 

Name: George McKean

 

Title: Senior Vice President

 

Signature Page

 



 

 

CANADIAN IMPERIAL BANK OF
COMMERCE, NEW YORK AGENCY,

 

as a Lender

 

 

 

 

 

By:

/s/ Trudy Nelson

 

Name: Trudy Nelson

 

Title: Authorized Signatory

 

 

 

 

 

By:

/s/ Daria Mahoney

 

Name: Daria Mahoney

 

Title: Authorized Signatory

 

Signature Page

 



 

 

TORONTO DOMINION (TEXAS), LLC,

 

as a Lender

 

 

 

 

 

By:

/s/ Savo Bozic

 

Name: Savo Bozic

 

Title: Authorized Signatory

 

Signature Page

 



 

 

GOLDMAN SACHS BANK USA,

 

as a New Lender

 

 

 

 

 

By:

/s/ Josh Rosenthal

 

Name: Josh Rosenthal

 

Title: Authorized Signatory

 

Signature Page

 



 

 

ABN AMRO CAPITAL USA LLC,

 

as a New Lender

 

 

 

 

 

By:

/s/ Kelly Hall

 

Name: Kelly Hall

 

Title: Vice President

 

 

 

 

 

By:

/s/ Darrell Holley

 

Name: Darrell Holley

 

Title: Managing Director

 

Signature Page

 



 

 

FIFTH THIRD BANK,

 

as a New Lender

 

 

 

 

 

By:

/s/ Jonathan H Lee

 

Name: Jonathan H Lee

 

Title: Director

 

Signature Page

 



 

 

PNC BANK, NATIONAL ASSOCIATION,

 

as a New Lender

 

 

 

 

 

By:

/s/ Sandra Aultman

 

Name: Sandra Aultman

 

Title: Managing Director

 

Signature Page

 


Exhibit 23.1

 

CONSENT OF INDEPENDENT AUDITORS

 

We hereby consent to the incorporation by reference in this Current Report on Form 8-K, dated September 8, 2016 of PDC Energy, Inc. (the “Company”) and in the Company’s Registration Statements on Form S-8 (Registration No. 333-189685, Registration No. 333-167945, Registration No. 333-137836, Registration No. 333-118222, and Registration No. 333-118215), the Company’s Registration Statement on Form S-3 (Registration No. 333-202853), and any prospectus supplement filed by the Company pursuant to Rule 424(b) under the Securities Act of 1933, as amended, of our report dated March 16, 2016, except as to Note 12, which is dated as of September 2, 2016, relating to the consolidated financial statements of Arris Petroleum Corporation.

 

 

/s/ EKS&H LLLP

 

EKS&H LLLP

 

September 8, 2016

Denver, Colorado

 


Exhibit 23.2

 

 

CONSENT OF CAWLEY, GILLESPIE & ASSOCIATES, INC.

INDEPENDENT PROFESSIONAL PETROLEUM ENGINEERS

 

We hereby consent to the references to Cawley, Gillespie and Associates, Inc. in the form and context in which they appear in the Current Report on Form 8-K, dated September 8, 2016 (the “Report”) of PDC Energy, Inc. (the “Company”). We further consent to the incorporation by reference of our report, dated July 1, 2016 in the Report and in the Company’s Registration Statements on Form S-8 (Registration No. 333-189685, Registration No. 333-167945, Registration No. 333-137836, Registration No. 333-118222 and Registration No. 333-118215), the Company’s Registration Statement on Form S-3 (File No. 333-202853) and any prospectus supplement filed by the Company pursuant to Rule 424(b) under the Securities Act of 1933, as amended.

 

/s/ Cawley, Gillespie and Associates, Inc.

Licensed Petroleum Engineers

 

Fort Worth, Texas

September 8, 2016

 


Exhibit 99.1

 

Arris Petroleum Corporation

 

Consolidated Financial Statements

and

Independent Auditors’ Report

December 31, 2015 and 2014

 



 

ARRIS PETROLEUM CORPORATION

 

Table of Contents

 

 

 

Page

 

 

 

Independent Auditors’ Report

 

1

 

 

 

Consolidated Financial Statements

 

 

 

 

 

Consolidated Balance Sheets

 

3

 

 

 

Consolidated Statements of Operations

 

4

 

 

 

Consolidated Statement of Changes in Stockholders’ Deficit

 

5

 

 

 

Consolidated Statements of Cash Flows

 

6

 

 

 

Notes to Consolidated Financial Statements

 

7

 



 

INDEPENDENT AUDITORS’ REPORT

 

Board of Directors and Stockholders

Arris Petroleum Corporation

Denver, Colorado

 

We have audited the accompanying consolidated financial statements of Arris Petroleum Corporation and its subsidiaries, which are comprised of the consolidated balance sheets as of December 31, 2015 and 2014, and the related consolidated statements of operations, changes in stockholders’ deficit, and cash flows for the years then ended, and the related notes to the consolidated financial statements.

 

MANAGEMENT’S RESPONSIBILITY FOR THE CONSOLIDATED FINANCIAL STATEMENTS

 

Management is responsible for the preparation and fair presentation of these consolidated 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 consolidated financial statements that are free from material misstatement, whether due to fraud or error.

 

AUDITORS’ RESPONSIBILITY

 

Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We conducted our audits in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free from material misstatement.

 

An audit involves performing procedures to obtain audit evidence about the amounts and disclosures in the consolidated financial statements. The procedures selected depend on the auditors’ judgment, including the assessment of the risks of material misstatement of the consolidated financial statements, whether due to fraud or error. In making those risk assessments, the auditors consider internal control relevant to the entity’s preparation and fair presentation of the consolidated 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 consolidated 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 consolidated financial statements referred to above present fairly, in all material respects, the financial position of Arris Petroleum Corporation and its subsidiaries as of December 31, 2015 and 2014, and the results of their operations and their cash flows for the years then ended in accordance with accounting principles generally accepted in the United States of America.

 

/s/ EKS&H LLLP

 

March 16, 2016, except as to Note 12, which is as of September 2, 2016

Denver, Colorado

 

2



 

ARRIS PETROLEUM CORPORATION

 

Consolidated Balance Sheets

 

 

 

December 31,

 

 

 

2015

 

2014

 

Assets

 

Current assets

 

 

 

 

 

Cash and cash equivalents

 

$

3,720,366

 

$

23,549,819

 

Revenue receivable

 

660,452

 

147,190

 

JIB receivable

 

1,277,575

 

 

Due from stockholders

 

5,167,774

 

 

Other current assets

 

414,726

 

141,478

 

Total current assets

 

11,240,893

 

23,838,487

 

Property and equipment

 

 

 

 

 

Oil and gas properties, successful efforts method

 

 

 

 

 

Proved properties

 

76,050,422

 

23,496,364

 

Unproved properties

 

58,904,693

 

62,392,823

 

Other property and equipment

 

608,217

 

205,519

 

Accumulated depreciation, depletion, amortization, and accretion

 

(5,552,375

)

(234,741

)

Property and equipment, net

 

130,010,957

 

85,859,965

 

Total assets

 

$

141,251,850

 

$

109,698,452

 

 

 

 

 

 

 

Liabilities and Stockholders’ Deficit

 

 

 

 

 

 

 

Current liabilities

 

 

 

 

 

Accounts payable

 

$

15,800,636

 

$

6,591,876

 

Accrued liabilities

 

5,749,725

 

5,276,517

 

Revenue payable

 

421,064

 

55,256

 

Total current liabilities

 

21,971,425

 

11,923,649

 

Asset retirement obligations

 

689,292

 

45,680

 

Total liabilities

 

22,660,717

 

11,969,329

 

Redeemable Convertible Senior Preferred Stock, $0.001 par value, 325,000 shares authorized, 175,043 (2015) and 102,476 (2014) shares issued and outstanding, liquidation preference of $192,218,143 (2015) and $108,551,697 (2014)

 

192,218,143

 

108,551,697

 

Commitments and contingencies (Note 5)

 

 

 

 

 

Stockholders’ deficit

 

 

 

 

 

Class A and Class B Common Stock, $0.001 par value, 210,000 shares authorized, 161,675 (2015) and 140,686 (2014) shares issued and outstanding

 

162

 

141

 

Additional paid-in capital

 

(17,549,895

)

(6,306,998

)

Accumulated deficit

 

(56,077,277

)

(4,515,717

)

Total stockholders’ deficit

 

(73,627,010

)

(10,822,574

)

Total liabilities and stockholders’ deficit

 

$

141,251,850

 

$

109,698,452

 

 

See notes to consolidated financial statements.

 

3



 

ARRIS PETROLEUM CORPORATION

 

Consolidated Statements of Operations

 

 

 

For the Year Ended

 

 

 

December 31,

 

 

 

2015

 

2014

 

Revenues

 

 

 

 

 

Oil revenues

 

$

2,259,778

 

$

30,124

 

Gas revenues

 

1,346,022

 

117,101

 

Total revenues

 

3,605,800

 

147,225

 

Operating expenses

 

 

 

 

 

Lease operating expenses

 

1,109,792

 

26,738

 

Gathering and processing

 

173,556

 

46,101

 

Production taxes

 

203,557

 

9,191

 

Geological and geophysical

 

3,056,049

 

450,924

 

Depreciation, depletion, amortization, and accretion

 

5,326,141

 

234,085

 

General and administrative expenses

 

5,912,755

 

3,571,776

 

Impairment of proved properties

 

38,661,606

 

 

Total operating expenses

 

54,443,456

 

4,338,815

 

Other (expense) income

 

 

 

 

 

(Loss) gain on sale of unproved property

 

(733,000

)

199,236

 

Interest income

 

9,096

 

22,614

 

Total other (expense) income

 

(723,904

)

221,850

 

Net loss

 

$

(51,561,560

)

$

(3,969,740

)

 

See notes to consolidated financial statements.

 

4



 

ARRIS PETROLEUM CORPORATION

 

Consolidated Statement of Changes in Stockholders’ Deficit

For the Years Ended December 31, 2015 and 2014

 

 

 

 

 

 

 

 

 

 

 

Additional

 

 

 

Total

 

 

 

Class A Common Stock

 

Class B Common Stock

 

Paid-In

 

Accumulated

 

Stockholders’

 

 

 

Shares

 

Amount

 

Shares

 

Amount

 

Capital

 

Deficit

 

Deficit

 

Balance - December 31, 2013

 

100,000

 

$

100

 

7,692

 

$

8

 

$

107,578

 

$

(545,977

)

$

(438,291

)

Issuance of Class A and Class B Common Stock

 

36,667

 

37

 

4,020

 

4

 

41,360

 

 

41,401

 

Redemptions and dividends

 

 

 

(7,693

)

(8

)

(36,667

)

 

(36,675

)

Equity issuance costs

 

 

 

 

 

(343,583

)

 

(343,583

)

Accrued dividends on Redeemable Convertible Senior Preferred Stock

 

 

 

 

 

(6,075,686

)

 

(6,075,686

)

Net loss

 

 

 

 

 

 

(3,969,740

)

(3,969,740

)

Balance - December 31, 2014

 

136,667

 

137

 

4,019

 

4

 

(6,306,998

)

(4,515,717

)

(10,822,574

)

Issuance of Class A and Class B Common Stock

 

34,898

 

35

 

629

 

1

 

35,490

 

 

35,526

 

Redemptions and dividends

 

(11,768

)

(12

)

(2,770

)

(3

)

(14,523

)

 

(14,538

)

Equity issuance costs

 

 

 

 

 

(107,215

)

 

(107,215

)

Accrued dividends on Redeemable Convertible Senior Preferred Stock

 

 

 

 

 

(11,156,649

)

 

(11,156,649

)

Net loss

 

 

 

 

 

 

(51,561,560

)

(51,561,560

)

Balance - December 31, 2015

 

159,797

 

$

160

 

1,878

 

$

2

 

$

(17,549,895

)

$

(56,077,277

)

$

(73,627,010

)

 

See notes to consolidated financial statements.

 

5



 

ARRIS PETROLEUM CORPORATION

 

Consolidated Statements of Cash Flows

 

 

 

For the Years Ended

 

 

 

December 31,

 

 

 

2015

 

2014

 

Cash flows from operating activities

 

 

 

 

 

Net loss

 

$

(51,561,560

)

$

(3,969,740

)

Adjustments to reconcile net loss to net cash used in operating activities

 

 

 

 

 

Depreciation, depletion, amortization, and accretion

 

5,326,141

 

234,085

 

Redeemable Convertible Senior Preferred Stock issued for services

 

182,500

 

83,300

 

Loss (gain) on sale of unproved property

 

733,000

 

(199,236

)

Impairment of proved properties

 

38,661,606

 

 

Changes in operating assets and liabilities

 

 

 

 

 

Accounts receivable

 

(1,790,837

)

(147,190

)

Other current assets

 

(273,248

)

(108,538

)

Accounts payable and accrued liabilities

 

2,394,789

 

146,574

 

Oil and gas revenue payable

 

365,808

 

55,256

 

 

 

45,599,759

 

64,251

 

Net cash used in operating activities

 

(5,961,801

)

(3,905,489

)

Cash flows from investing activities

 

 

 

 

 

Investment in oil and gas properties

 

(77,204,249

)

(64,485,241

)

Acquisition of oil and gas properties

 

(4,760,000

)

 

Proceeds from sale of unproved property

 

1,426,000

 

3,820,449

 

Purchase of furniture and equipment

 

(402,699

)

(186,085

)

Net cash used in investing activities

 

(80,940,948

)

(60,850,877

)

Cash flows from financing activities

 

 

 

 

 

Proceeds from issuance of common stock

 

35,526

 

41,401

 

Proceeds from issuance of Redeemable Convertible Senior Preferred Stock

 

67,990,241

 

83,668,983

 

Redemption of Redeemable Convertible Preferred Stock

 

(830,718

)

 

Redemption of common stock

 

(14,538

)

(36,675

)

Equity issuance costs

 

(107,215

)

(343,583

)

Net cash provided by financing activities

 

67,073,296

 

83,330,126

 

Net (decrease) increase in cash and cash equivalents

 

(19,829,453

)

18,573,760

 

Cash and cash equivalents - beginning of year

 

23,549,819

 

4,976,059

 

Cash and cash equivalents - end of year

 

$

3,720,366

 

$

23,549,819

 

Supplemental disclosure of non-cash activity:

 

 

 

 

 

Current liabilities related to oil and gas property additions

 

$

19,008,998

 

$

11,721,819

 

Capitalized asset retirement obligations

 

$

363,084

 

$

45,680

 

Acquired asset retirement obligations

 

$

272,022

 

$

 

Contribution of undeveloped leaseholds for Redeemable Convertible Senior Preferred Stock

 

$

 

$

13,139,808

 

Accrued Redeemable Convertible Senior Preferred Stock dividends

 

$

11,156,649

 

$

6,075,686

 

Redeemable Convertible Senior Preferred Stock in subscription receivable

 

$

5,167,774

 

$

 

 

See notes to consolidated financial statements.

 

6



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 1 - Description of Business and Summary of Significant Accounting Policies

 

Arris Petroleum Corporation (the “Company”) is an independent energy company with substantially all of its producing oil and gas property located in the Permian Basin.

 

The Company was formed in the state of Delaware on October 16, 2013 with the purpose of acquiring and developing oil and gas properties located in the United States and commenced substantial operations in 2014.

 

Principles of Consolidation

 

The accompanying consolidated financial statements include the accounts of Arris Petroleum Corporation and its wholly owned subsidiaries, Arris Operating Company, LLC; Arris Delaware Basin, LLC; Kimmeridge West Texas, LLC; and Arris Reeves Infrastructure, LLC. All intercompany accounts and transactions have been eliminated in consolidation.

 

Use of Estimates

 

The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures 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. Actual results could differ from those estimates.

 

The impact of oil and gas prices has a significant influence on estimates made by management. Changes in oil and gas prices directly affect the economic limits of estimated oil and gas reserves. These economic limits have significant effects upon estimated reserve quantities and valuations. These estimates are the basis for the calculation of depreciation, depletion, and amortization for the oil and gas properties and the assessment as to whether an impairment of such properties is required. In addition, significant estimates include the estimated cost and timing related to asset retirement obligations and the recoverability of unproved properties.

 

Cash and Cash Equivalents

 

The Company considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. The Company continually monitors its positions with, and the credit quality of, the financial institutions with which it invests. As of the balance sheet date, and periodically throughout the year, the Company has maintained balances in various operating accounts in excess of federally insured limits.

 

Accounts Receivable

 

The Company accrues for oil and gas sales based on actual production dates. Joint interest billings represent monthly billings to working interest owners in the properties the Company operates. These receivables are due within 30 days of billing, with a right of offset against revenues due to working interest owners in the properties. No interest is charged on past-due balances. All receivables are reviewed periodically, and appropriate actions are taken on past-due amounts, if any.

 

7



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 1 - Description of Business and Summary of Significant Accounting Policies (continued)

 

Concentrations of Credit Risk

 

The Company grants credit in the normal course of business to oil and gas purchasers in the United States. Collectibility of the Company’s oil and gas sales is dependent upon the financial condition of the Company’s purchasers as well as general economic conditions of the industry. As of December 31, 2015, three purchasers accounted for 75% of oil and gas sales and 89% of revenue receivable.  As of December 31, 2014, two purchasers accounted for 100% of the oil and gas sales and revenue receivable.

 

Accounting for Oil and Gas Properties

 

The Company follows the successful efforts method of accounting for its oil and gas properties. The Company does not capitalize general and administrative expenses directly identifiable with such activities. Costs of unsuccessful exploration efforts are expensed in the period it is determined that such costs are not recoverable through future net revenues. Geological and geophysical costs and delay rentals are expensed as incurred. The cost of development wells are capitalized whether productive or non-productive. Upon the sale of proved properties, the cost and accumulated depletion are removed from the accounts, and any gain or loss is reflected in the consolidated statement of operations. If it is determined that the sale of proved properties did not significantly affect the units-of-production depletion rate, the sale is treated as a normal retirement with no gain or loss recognized.

 

Capitalized costs for unproved oil and gas properties are assessed at least annually to determine if an impairment in value needs to be recognized. There were no unproved property impairments during the years ended December 31, 2015 and 2014. For sales of partial interests in unproved properties, the Company treats the proceeds as a recovery of costs with no gain recognized until all costs have been recovered. During the years ended December 31, 2015 and 2014, the Company recognized (loss) gain of $(733,000) and $199,236, respectively, related to the sales of an entire interest in unproved properties.

 

8



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 1 - Description of Business and Summary of Significant Accounting Policies (continued)

 

Accounting for Oil and Gas Properties (continued)

 

The Company accounts for suspended exploratory well costs in accordance with the provisions of Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 932, Extractive Activities - Oil and Gas . There were no exploratory wells-in-progress as of December 31, 2015 as all exploratory well costs were transferred to proved properties during the year. Exploratory wells-in-progress as of December 31, 2014 represents one well included in unproved properties that was spud in the fourth quarter of 2014, which the Company fully evaluated in 2015. The following table for the years ended December 31, 2015 and 2014 reflects the net change in capitalized exploratory well costs.

 

 

 

For the Year Ended
December 31,

 

 

 

2015

 

2014

 

Beginning balance

 

$

11,793,120

 

$

 

Additions to capitalized exploratory well costs pending the determination of proved reserves

 

1,180,372

 

11,793,120

 

Reclassifications to proved properties due to the determination of proved reserves

 

(12,973,492

)

 

Ending balance

 

$

 

$

11,793,120

 

 

Depreciation, depletion, and amortization of proved oil and gas properties is calculated using the units-of-production method based on proved reserves and estimated salvage values. For the years ended December 31, 2015 and 2014, the Company recorded $5,234,936 and $211,914, respectively, of depreciation and depletion expense on oil and gas properties. As of December 31, 2015 and 2014, the Company had approximately $10,091,984 and $8,116,097, respectively, designated as developmental wells-in-progress, which is included in proved oil and gas properties. The costs related to developmental wells-in-progress were excluded from the units-of-production depletion calculation.

 

The Company assesses the recoverability of its capitalized costs for its proved oil and gas properties periodically, or when circumstances indicate there is a need for such review. To determine if a depletable unit (generally defined as an individual field) is impaired, the Company compares the carrying value of the depletable unit to the undiscounted future net cash flows by applying estimated future prices over the economic lives of the reserves. For each depletable unit determined to be impaired, an impairment loss equal to the difference between the carrying value and the estimated fair value of the depletable unit will be recognized. Fair value, on a depletable unit basis, is estimated to be the present value of expected future cash flows computed by applying estimated future oil and gas prices, as determined by management, to estimated future production of oil and gas reserves over the economic lives of the reserves and the application of a discount rate commensurate with the risk associated with realizing the expected cash flows. The discount rate is a rate that management believes is representative of current market conditions and includes estimates for the risk premium. Due to low oil and gas prices, the Company recorded proved property impairments of $38,661,606 and $0, during the years ended December 31, 2015 and 2014, respectively.

 

9



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 1 - Description of Business and Summary of Significant Accounting Policies (continued)

 

Property and Equipment

 

Property and equipment are stated at cost. Depreciation is provided utilizing the straight-line method over the estimated useful lives for owned assets, ranging from five to seven years.

 

Reclassifications

 

Certain amounts in the 2014 consolidated financial statements have been reclassified to conform to the 2015 presentation. These reclassifications had no effect on previously reported results of operations or retained earnings.

 

Revenue Recognition

 

Natural gas revenues are recognized when the title and risk pass to the purchaser. The Company records its share of revenues based on its share of proceeds. The Company sells the majority of its products soon after production at various locations, including the wellhead, at which time title and risk of loss pass to the buyer.

 

Gas imbalances occur when the Company sells more or less than its entitled ownership percentage of total gas production. Any amount received in excess of the Company’s share is treated as a liability. If the Company receives less than its entitled share, the underproduction is recorded as a receivable.

 

At December 31, 2015 and 2014, the Company did not have any material gas imbalances.

 

Oil revenues are recognized when production is sold to a purchaser at a fixed or determinable price, delivery has occurred, title is transferred, and collectibility is assured.

 

Income Taxes

 

The Company recognizes deferred tax liabilities and assets based on the differences between the tax basis of assets and liabilities and their reported amounts in the consolidated financial statements that will result in taxable or deductible amounts in future years. The Company’s temporary differences result primarily from depletion and impairments of oil and gas properties under the successful efforts method of accounting.

 

The Company’s deferred income taxes include certain future tax benefits. The Company records a valuation allowance against any portion of those deferred income tax assets when it believes, based on the weight of available evidence, it is more likely than not that some portion or all of the deferred income tax asset will not be realized.

 

The Company evaluates its tax positions taken or expected to be taken in the course of preparing the Company’s tax returns to determine whether the tax positions will more likely than not be sustained by the applicable tax authority. Tax positions not deemed to meet the more-likely-than-not threshold are not recorded as a tax benefit or expense in the current year. Interest and penalties, if applicable, are recorded in the period assessed as general and administrative expenses. However, no interest or penalties have been assessed for the years ended December 31, 2015 and 2014.

 

10



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 1 - Description of Business and Summary of Significant Accounting Policies (continued)

 

Stock-Based Compensation

 

The Company recognizes compensation expense for stock-based awards when all performance and service conditions are probable of being satisfied (generally upon a liquidation event).

 

Subsequent Events

 

On January 14, 2016 and March 14, 2016, the Company issued an additional 21,000 shares and 11,139 shares, respectively, of Redeemable Convertible Preferred Stock for $1,000 per share.

 

In January 2016, the Company commenced midstream operations under its Arris Reeves Infrastructure, LLC subsidiary to transport crude oil and natural gas via the Reeves infrastructure pipeline.

 

The Company has evaluated all subsequent events through the auditors’ report date of March 16, 2016, which is the date the consolidated financial statements were available for issuance. There were no additional material subsequent events that required recognition or additional disclosure in these consolidated financial statements.  See Note 12.

 

Note 2 - Acquisitions and Divestitures

 

In June 2015, the Company entered into a purchase and sale agreement with an unrelated party to acquire the right, title, and interest in and to several oil and gas properties totaling $4,760,000. The Company recorded the estimated fair value of the identifiable assets acquired as of the acquisition date.

 

See below for a summary of the assets acquired and liabilities assumed with this transaction:

 

Purchase price

 

 

 

Cash consideration

 

$

4,760,000

 

Recognized amounts of identifiable assets and liabilities acquired

 

 

 

Proved oil and gas properties

 

$

3,561,922

 

Pipeline and gas gathering equipment

 

951,575

 

Unproved properties

 

518,525

 

Asset retirement obligation assumed

 

(272,022

)

Total identifiable net assets

 

$

4,760,000

 

 

11



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 2 - Acquisitions and Divestitures (continued)

 

To determine the fair value of the proved oil and gas properties acquired in the business combination, the Company used an income approach based on a discounted cash flow model and made market assumptions as to future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development and operating costs, projections of future rates of production, expected recovery rates, and risk-adjusted discount rates. The Company determined the appropriate discount rates used for the discounted cash flow analyses by using a weighted-average cost of capital from a market participant perspective plus property-specific risk premiums for the assets acquired. The pipeline and gas gathering equipment acquired is included in proved oil and gas properties and is subject to units-of-production depletion and impairment at the depletable unit.

 

In December 2015, the Company entered into a purchase and sale agreement with an unrelated party to divest certain unproved oil and gas properties. The properties were sold for $1,426,000 in cash, resulting in a loss of $733,000.

 

In June 2014, the Company entered into a purchase and sale agreement with an unrelated party to divest all of its unproved acreage in Irion County. The properties were sold for $1,626,300 in cash, resulting in a gain of $199,236.

 

In November 2014, the Company entered into a purchase and sale agreement with an unrelated party to divest certain unproved oil and gas properties. The properties were sold for $2,194,149 in cash, net of broker fees; no gain or loss was recorded as a result of this sale.

 

Note 3 - Fair Value Measurements

 

The Company applies the authoritative guidance applicable to all financial assets and liabilities required to be measured and reported at fair value on a recurring basis, as well as to non-financial assets and liabilities measured at fair value on a non-recurring basis, including impairments of proved oil and gas properties and other long-lived assets and asset retirement obligations initially measured at fair value. The fair value of an asset or liability is the amount that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. The Company maximizes the use of observable inputs and minimizes the use of unobservable inputs when measuring fair value. Observable inputs are inputs that market participants would use in valuing the asset or liability based on market data obtained from sources independent of the Company. Unobservable inputs are inputs that reflect the Company’s assumptions of what market participants would use in valuing the asset or liability based on the best information available in the circumstances.

 

12



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 3 - Fair Value Measurements (continued)

 

Financial and non-financial assets and liabilities are classified within the valuation hierarchy based upon the lowest level of input that is significant to the fair value measurement. The Company’s policy is to recognize transfers in and out of the fair value hierarchy as of the end of the reporting period in which the event or change in circumstances caused the transfer. The hierarchy is organized into three levels based on the reliability of the inputs as follows:

 

Level 1:                             Quoted prices in active markets for identical assets or liabilities;

 

Level 2:                             Quoted prices in active markets for similar assets and liabilities and inputs, quoted prices for identical or similar assets or liabilities in markets that are not active, and model-derived valuations whose inputs or significant value drivers are observable; or

 

Level 3:                             Unobservable pricing inputs in which there is little or no market data, which requires the reporting entity to develop its own assumptions.

 

Recurring Fair Value Measurements

 

The Company did not have any assets or liabilities that were required to be measured at fair value on a recurring basis as December 31, 2015 and 2014.

 

Non-Recurring Fair Value Measurements

 

The following table presents the Company’s non-financial assets and liabilities that were measured at fair value on a non-recurring basis during the year ended December 31, 2015 by level within the fair value hierarchy:

 

Description

 

Level 1

 

Level 2

 

Level 3

 

Total

 

Asset

 

 

 

 

 

 

 

 

 

Proved oil and gas properties:

 

 

 

 

 

 

 

 

 

Culberson field

 

$

 

$

 

$

9,799,797

 

$

9,799,797

 

Liability

 

 

 

 

 

 

 

 

 

Asset retirement obligations

 

$

 

$

 

$

363,084

 

$

363,084

 

 

The following table presents the Company’s non-financial assets and liabilities that were measured at fair value on a non-recurring basis during the year ended December 31, 2014 by level within the fair value hierarchy:

 

Description

 

Level 1

 

Level 2

 

Level 3

 

Total

 

Liability

 

 

 

 

 

 

 

 

 

Asset retirement obligations

 

$

 

$

 

$

45,680

 

$

45,680

 

 

13



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 3 - Fair Value Measurements (continued)

 

Non-Recurring Fair Value Measurements (continued)

 

Proved oil and gas properties are recorded at fair value if the carrying value exceeds undiscounted cash flows. The Company uses Level 3 inputs and the income valuation technique to measure the fair value of proved properties using discount rates and year-end commodity future prices selected by the Company’s management. The discount rate used was 10%, which is a rate that management believes is representative of current market conditions and includes estimates for the risk premium. The price forecast used for crude oil was the December 31, 2015 New York Mercantile (“NYMEX”) WTI price, adjusted for an estimated differential. The price forecast used for natural gas was the December 31, 2015 NYMEX Henry Hub price, adjusted for an estimated differential. During the year ended December 31, 2015, the Company valued its Culberson field at $9,799,797, which resulted in an impairment of $38,661,606. The impairment was driven primarily by the significant decline in commodity prices during the year ended December 31, 2015.

 

Fair value used in the initial recognition of asset retirement obligations and any subsequent upward changes in estimates is determined under the income approach using the present value of expected future remediation and dismantlement costs, incorporating the Company’s best estimate of inputs used by industry participants when valuing similar liabilities. Accordingly, the fair value is based on unobservable pricing inputs and, therefore, is considered a Level 3 measurement in the fair value hierarchy. During the years ended December 31, 2015 and 2014, the Company recorded asset retirement obligations of $363,084 and $45,680, respectively. See Note 4 for additional information.

 

Other assets and liabilities not measured at fair value on a recurring basis include cash and cash equivalents, accounts receivable, accounts payable, accrued liabilities, and revenue payable. The consolidated financial statement carrying amounts of these items approximate their fair values due to their short-term nature.

 

Note 4 - Asset Retirement Obligations

 

The Company follows the provisions of ASC Topic 410, Asset Retirement and Environmental Obligations . This topic requires that the fair value of a liability for an asset retirement obligation be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The associated asset retirement costs are capitalized as part of the carrying amount of the asset. The asset retirement obligations are allocated to operating expenses by using a systematic, rational method. The Company’s asset retirement obligations relate to the plugging and abandoning of its oil and gas wells and the reclamation of its well locations. The revisions made during the year ended December 31, 2015 were due to changes in estimated abandonment costs obtained by the Company based on current economic factors.

 

14



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 4 - Asset Retirement Obligations (continued)

 

A reconciliation of the changes in the Company’s liabilities are as follows:

 

 

 

December 31,

 

 

 

2015

 

2014

 

Beginning asset retirement obligations

 

$

45,680

 

$

 

Liabilities acquired

 

272,022

 

 

Liabilities incurred

 

219,517

 

45,680

 

Revisions

 

143,567

 

 

Accretion

 

8,506

 

 

Long-term asset retirement obligations

 

$

689,292

 

$

45,680

 

 

Note 5 - Commitments and Contingencies

 

Operating Leases

 

The Company leases facilities, equipment, and vehicles under non-cancelable operating leases. Rent expense for the years ended December 31, 2015 and 2014 was $256,554 and $115,877, respectively.

 

Future minimum lease payments under these leases are approximately as follows:

 

Year Ending December 31,

 

 

 

2016

 

$

161,690

 

2017

 

54,916

 

 

 

$

216,606

 

 

Litigation

 

In the normal course of business, the Company is party to litigation from time to time. The Company maintains insurance to cover certain actions and believes that resolution of such litigation will not have a material adverse effect on the Company.

 

15



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 5 - Commitments and Contingencies (continued)

 

Investor Consulting Agreement

 

On January 29, 2014, the Company entered into an agreement with one of its investors whereby the investor has the right to nominate up to three consultants whom the Company will train in the upstream oil and gas industry (“Investor Consultants”). As of December 31, 2015 and 2014, the Company was training one and two Investor Consultants, respectively. Direct payroll and related costs of the Investor Consultants are to be paid by the investor; however, the Company is required to pay $250,000 per year to the investor, prorated for partial years, regardless of the number of Investor Consultants being trained. The payment for services is to be made in shares of Redeemable Convertible Senior Preferred Stock (Note 6), valued at $1,000 per share. During 2015, the Company incurred expense of $182,500 related to Investor Consultants, which represented a partial year of services and was paid with approximately 183 shares of Redeemable Convertible Senior Preferred Stock. During 2014, the Company incurred expense of $83,300 related to Investor Consultants, which represented a partial year of services and was paid with approximately 83 shares of Redeemable Convertible Senior Preferred Stock. The Investor Consultants are providing services to the Company, and the value of the professional services are comparable to the value of the Redeemable Convertible Senior Preferred Stock issued.

 

Management Employment Agreements

 

The Company has employment agreements with certain members of management. Under the terms of these agreements, the Company has agreed, under certain circumstances, to pay salaries and benefits to these members of management until the termination of the employment agreements. No provisions have been made in the accompanying consolidated balance sheet for these commitments.

 

Management Separation Agreements

 

During the year ended December 31, 2015, the Company entered into separation agreements with certain members of management.  Pursuant to these separation agreements, these terminated members of management are entitled to receive up to $733,333 upon the achievement of certain events after their termination, as defined.  As of December 31, 2015, the Company has not recorded an accrual related to these separation agreements as the events are not considered probable at December 31, 2015.

 

Shut-In Wells

 

In November 2015, the third-party gas plant servicing the Company’s wells in Culberson County was closed due to a gas processing plant explosion. As a result, those wells are shut-in indefinitely pending the reopening of the plant.

 

16



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 6 - Redeemable Convertible Senior Preferred Stock

 

The Company is authorized to issue up to 350,000 preferred shares, par value $0.001. Of the 350,000 preferred shares authorized, the Company has designated 325,000 shares as Redeemable Convertible Senior Preferred Stock (“Senior Preferred Stock”). As of December 31, 2015 and 2014, there were 175,043 and 102,476 shares of Senior Preferred Stock issued and outstanding, respectively, issued at an original issuance price of $1,000 per share (“Original Issue Price”). As of December 31, 2015, the Company had a remaining capital commitment on the Senior Preferred Stock of $32,166,145.

 

During the year ended December 31, 2015, the Company redeemed 774 Senior Preferred shares for $773,772, plus the related cumulative preferred return of $56,946, as part of separation agreements entered into with certain members of management (Note 5).

 

At December 31, 2015, the Company had $5,167,774 recorded as due from stockholders on the accompanying consolidated balance sheet relating to shares issued in December 2015. The balance of $5,167,774 was received by the Company on January 4, 2016.

 

Voting

 

The Senior Preferred Stock holders are entitled to vote as a separate class on certain matters, including (i) any amendment to the certificate of incorporation that would adversely affect the rights and preferences of Senior Preferred Stock; (ii) adoption of a Certification of Designation with respect to any series of preferred shares; (iii) any amendment to the Bylaws of the Company proposed by the holders of the Common Stock; and (iv) consummation by the Company of any contract for a liquidation event, as defined (“Liquidation Event”). In instances where both holders of Common Stock and Senior Preferred Stock have voting rights with respect to a matter for which a vote is being taken, holders will vote as separate classes. Approval of such matter will require majority approval of each voting class.

 

Conversion

 

Holders of the Senior Preferred Stock may elect to convert some or all of the Senior Preferred Stock within 30 days after the closing of an initial public offering (“IPO”) into the class of stock in the IPO at the IPO price.

 

Dividends

 

Holders of the Senior Preferred Stock are entitled to a cumulative preferred return of 8% per annum, compounded continually on the Adjusted Capital Balance with respect to such share through the earlier of (i) the redemption date of such share or (ii) a Liquidation Event, as defined. The Adjusted Capital Balance is defined as (i) the Original Issue Price, less (ii) the aggregate amount of all distributions made by the Company with respect to such share prior to such date, if any. As of December 31, 2015 and 2014, the Company recorded cumulative accrued Senior Preferred Stock dividends of $17,175,389 and $6,075,686.

 

17



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 6 - Redeemable Convertible Senior Preferred Stock (continued)

 

Liquidation

 

In the event of liquidation, dissolution, or winding up of the Company, the holders of the Senior Preferred Stock will be paid in cash for each share of Senior Preferred Stock held in an amount equal to the Original Issue Price, plus all accrued unpaid dividends (the “Liquidation Preference”), before any payment is made to any Common Stock holders. If the assets of the Company available for distribution to the holders of shares of the Senior Preferred Stock are insufficient to permit payment in full to such holders of the sums that such holders are entitled to receive in such case, then all of the assets available for distribution to holders of shares of the Senior Preferred Stock will be distributed among and paid to such holders ratably in proportion to the amounts that would be payable if such assets were sufficient to permit full payment.

 

Redemption

 

The Company may, but is not obligated to, redeem all or any portion of the Senior Preferred Stock at the Liquidation Preference. Upon a Liquidation Event, the Company is required to repurchase the Senior Preferred Stock with the proceeds received. Due to this conditional redemption feature, the Senior Preferred Stock has been classified outside of permanent equity.

 

Note 7 - Stockholders’ Deficit

 

The Company is authorized to issue up to 210,000 shares of Common Stock, par value $0.001, which is divided into two classes: Class A Common Stock (“Class A Stock”) and Class B Common Stock (“Class B Stock”) (collectively, “Common Stock”). There were 159,797 Class A Stock shares and 1,878 Class B Stock shares issued and outstanding as of December 31, 2015. There were 136,667 Class A Stock shares and 4,019 Class B Stock shares issued and outstanding as of December 31, 2014. During the year ended December 31, 2015, the Company redeemed 11,768 Class A Stock shares and 2,770 Class B Stock shares for $1 per share as part of separation agreements entered into with certain members of management (Note 5).

 

Voting

 

Each holder of Common Stock will be entitled to one vote for each share.

 

Conversion

 

Upon achievement of the Required Investor Return, each outstanding share of Class B Stock will be automatically converted into Class A Stock.

 

If, immediately prior to the effective date of an IPO, the Required Investor Return has not been achieved, all outstanding shares of Class B Stock will automatically convert into fractional shares of Class A Stock based upon the actual rate of return achieved through that date.

 

18



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 7 - Stockholders’ Deficit (continued)

 

Dividends

 

Holders of the Common Stock shall not be entitled to dividends until the Senior Preferred Stock has been redeemed at the Liquidation Preference and, after that, only when declared by the Board of Directors. When and if dividends are properly declared on the Common Stock:

 

a.          The holders of the outstanding shares of Class A Stock will be entitled to receive dividends with respect to each share of Class A Stock, prior to the payment of any dividend or other distribution on shares of Class B Stock, until a required investor return (“Required Investor Return”) has been achieved and paid in full.

 

b.          Once the Required Investor Return has been achieved and paid in full, the holders of all Common Stock will be entitled to receive all further dividends from the Company.

 

c.           Thereafter, all dividends with respect to shares of each class of Common Stock will be paid pro rata and in like matter to all of the holders entitled thereto.

 

Liquidation

 

In the event of liquidation, dissolution, or winding up of the Company, the assets of the Company legally available to the stockholders, after payment in full of the Liquidation Preference to the Senior Preferred Stock, will be distributed to the holders of Common Stock, first to the holders of Class A Stock, until the Required Investor Return has been achieved and paid in full. Once this is achieved, the holders of Common Stock will be entitled to all residual assets of the Company pro rata without limit.

 

Management Incentive Units

 

The Class B Stock is available to management only, and a portion of Class A Stock is also held by management (“Management Incentive Units”). The number of Class A Stock and Class B Stock shares held by management as of December 31, 2015 was 7,990 and 1,879, respectively. The number of Class A Stock and Class B Stock shares held by management as of December 31, 2014 was 17,083 and 4,019, respectively. The Management Incentive Units were purchased with cash at $1.00 per share and are generally subject to vesting over four years. As of December 31, 2015 and 2014, 4,935 and 5,276 shares were vested, respectively. If subsequent issuances of Class A Stock and Class B Stock occur, management is entitled to maintain their relative percentage of Class A Stock and Class B Stock without further consideration, subject to the original vesting schedule.

 

Note 8 - Income Taxes

 

The Company’s deferred tax assets or liabilities are computed based on the difference between the financial statement basis and tax basis of certain assets and liabilities using the enacted marginal tax rate. Deferred income tax expenses or benefits are based on the changes in the asset or liability from year to year.

 

19



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 8 - Income Taxes (continued)

 

The reconciliation between the statutory rate and the effective rate is mainly attributable to the valuation allowance on the deferred tax assets and items that are not deductible for tax, such as meals and entertainment.

 

The following is a summary of the Company’s deferred tax assets and liabilities:

 

 

 

December 31,

 

 

 

2015

 

2014

 

Deferred tax assets

 

 

 

 

 

Net operating loss carryforwards

 

$

9,869,160

 

$

2,788,882

 

Organizational fees

 

26,404

 

28,462

 

Oil and gas property

 

11,265,387

 

 

Asset retirement obligation

 

261,996

 

 

Total deferred tax assets

 

21,422,947

 

2,817,344

 

Deferred tax liabilities

 

 

 

 

 

Oil and gas property

 

 

(1,064,580

)

Other

 

(116,916

)

(39,796

)

Total deferred tax liabilities

 

(116,916

)

(1,104,376

)

Net deferred tax asset

 

21,306,031

 

1,712,968

 

Less: valuation allowance

 

(21,306,031

)

(1,712,968

)

Deferred tax asset

 

$

 

$

 

 

In November 2015, the FASB issued Accounting Standards Update No. 2015-17, Balance Sheet Classification of Deferred Taxes . This guidance requires that all deferred tax assets and liabilities, along with any related valuation allowance, be classified as non-current on the balance sheet. This guidance may either be applied prospectively or retrospectively. The Company early adopted this guidance during the year ended December 31, 2015.

 

The Company has pre-tax net operating loss carryforwards of as of December 31, 2015 and 2014 of $25,964,982 and $7,337,329, respectively, which expire before 2036 and 2035, respectively. Internal Revenue Code Section 382 imposes limitations on a Company’s ability to recognize certain deferred tax assets upon a change of control of the Company. During 2014, the Company had a change of control event under Section 382, which will limit its ability to utilize its deferred tax assets, including net operating loss carryforwards, to offset future taxable income. The approximate amount of net operating losses subject to the Section 382 limitation is $650,000.

 

A valuation allowance is provided when it is more likely than not that all or some of the deferred income tax assets will not be realized. Based upon cumulative losses since inception and projections of future taxable income, the Company has recorded a valuation allowance of $21,306,031 and $1,712,968 at December 31, 2015 and 2014, respectively.

 

20



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 8 - Income Taxes (continued)

 

The Company does not believe that it has any uncertain tax positions. It is the Company’s policy to recognize interest and penalties related to uncertain tax benefits in income tax expense. As of December 31, 2015 and 2014, the Company has not recognized any interest or penalties in its statement of operations or balance sheet.

 

Note 9 - Employee Benefit Plan

 

The Company has a 401(k) Plan (the “Plan’’) to provide retirement and incidental benefits for its employees. Employees may contribute from 1% to 80% of their annual compensation to the Plan, limited to a maximum annual amount as updated annually by the IRS. The Company matches employee contributions dollar for dollar up to a maximum of 6% per year per person. All matching contributions vest immediately. In addition, the Plan provides for discretionary matching contributions as determined by the Board of Directors. Such contributions to the Plan are allocated among eligible participants in the proportion of their salaries to the total salaries of all participants. During the years ended December 31, 2015 and 2014, the Company contributed $93,133 and $87,293, respectively, as discretionary matching contributions.

 

Note 10 - Related Party Transactions

 

During 2014, one investor contributed unproved oil and gas properties with an estimated fair value of $13,139,808 in exchange for 13,139 shares of Senior Preferred Stock. No such contributions occurred during 2015.

 

Note 11 - Supplemental Oil and Gas Information (Unaudited)

 

Costs Incurred in Oil and Gas Producing Activities

 

Costs incurred in oil and gas property acquisition, exploration, and development activities, whether capitalized or expensed, are summarized as follows:

 

 

 

For the Year Ended
December 31,

 

 

 

2015

 

2014

 

Development costs

 

$

62,493,919

 

$

18,272,490

 

Exploration costs

 

4,236,421

 

12,244,044

 

Acquisitions

 

 

 

 

 

Proved properties

 

4,241,475

 

 

Unproved properties

 

21,698,746

 

59,398,419

 

Total, including asset retirement obligation

 

$

92,670,561

 

$

89,914,953

 

 

21



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 11 - Supplemental Oil and Gas Information (Unaudited) (continued)

 

Oil and Gas Reserve Quantities

 

The reserves at December 31, 2015 presented below were prepared by the independent engineering firm Cawley, Gillespie & Associates, Inc.  The reserves at December 31, 2014 presented below were prepared internally by the Company’s petroleum engineer.  All proved reserves are located within the Reeves and Culberson Counties in Texas. Estimates of proved reserves are inherently imprecise and are continually subject to revision based on production history, results of additional exploration and development, price changes, and other factors.

 

Guidelines prescribed in FASB Topic 932, Extractive Industries — Oil and Gas , have been followed for computing a standardized measure of future net cash flows and changes therein relating to estimated proved reserves.  Future cash inflows and future production and development costs are determined by applying prices and costs, including transportation, quality, and basis differentials, to the year-end estimated quantities of oil and gas to be produced in the future.  The resulting future net cash flows are reduced to present value amounts by applying a 10% annual discount factor.  Future operating costs are determined based on estimates of expenditures to be incurred in producing the proved oil and gas reserves in place at the end of the period using year-end costs and assuming continuation of existing economic conditions, plus overhead incurred.  Future development costs are determined based on estimates of capital expenditures to be incurred in developing proved oil and gas reserves.

 

The assumptions used to compute the standardized measure are those prescribed by the FASB and the SEC.  These assumptions do not necessarily reflect the Company’s expectations of actual revenues to be derived from those reserves, nor their present value.  The limitations inherent in the reserve quantity estimation process, as discussed previously, are equally applicable to the standardized measure computations since these reserve quantity estimates are the basis for the valuation process.  Reserve estimates are inherently imprecise and estimates of new discoveries and undeveloped locations are more imprecise than estimates of established proved producing oil and gas properties.  Accordingly, these estimates are expected to change as future information becomes available.

 

22



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 11 - Supplemental Oil and Gas Information (Unaudited) (continued)

 

Oil and Gas Reserve Quantities (continued)

 

The following table sets forth information for the years ended December 31, 2015 and 2014 with respect to changes in the Company’s proved (i.e., proved developed and undeveloped) reserves:

 

 

 

(Mbbl)
Crude Oil

 

(MMcf)
Natural Gas

 

December 31, 2013

 

 

 

Extension, discoveries, and other additions

 

547.1

 

3,517.4

 

Revisions

 

 

 

Production

 

(0.6

)

(31.3

)

December 31, 2014

 

546.5

 

3,486.1

 

Extension, discoveries, and other additions

 

2,901.6

 

18,499.4

 

Revisions

 

(228.5

)

852.8

 

Production

 

(58.8

)

(638.4

)

December 31, 2015

 

3,160.8

 

22,199.9

 

Proved developed reserves, included above:

 

 

 

 

 

December 31, 2014

 

156.8

 

2,255.8

 

December 31, 2015

 

1,050.7

 

11,447.9

 

Proved undeveloped reserves, included above:

 

 

 

 

 

December 31, 2014

 

389.7

 

1,230.3

 

December 31, 2015

 

2,110.1

 

10,752.0

 

 

Notable changes in proved reserves for the year ended December 31, 2015 relate to extensions and discoveries resulting from the drilling of one successful exploratory well in Culberson county and three successful exploratory wells in Reeves County.

 

Standardized Measure of Discounted Future Net Cash Flows

 

As of December 31, 2015, the reserves are comprised of 46.1% crude oil and 53.9% natural gas, on an energy equivalent basis of one barrel per six Mcf. The following values for the 2015 proved reserves were derived based on prices of $50.28 per Bbl of crude oil and $2.59 per Mcf of natural gas. The following values for the 2014 proved reserves were derived based on prices of $76.55 per Bbl of crude oil and $4.04 per Mcf of natural gas. These prices were based on the 12-month arithmetic average first-of-month price for January 2015 through December 2015 and January 2014 through December 2014, respectively. The crude oil pricing was based on the West Texas Intermediate price and the natural gas pricing was based on the Henry Hub price. All prices have been adjusted for transportation, quality, and basis differentials.

 

23



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 11 - Supplemental Oil and Gas Information (Unaudited) (continued)

 

Standardized Measure of Discounted Future Net Cash Flows (continued)

 

The following summary sets forth the Company’s future net cash flows relating to proved oil and gas reserves based on the standardized measure prescribed in ASC Topic 932 (in thousands):

 

 

 

As of
December 31,

 

 

 

2015

 

2014

 

Future crude oil and natural gas sales

 

$

202,923

 

$

55,910

 

Future production costs

 

(64,859

)

(13,235

)

Future development costs

 

(46,839

)

(7,050

)

Future income tax expense

 

(1,065

)

(155

)

Future net cash flows

 

90,160

 

35,470

 

10% annual discount

 

(44,897

)

(17,160

)

Standardized measure of discounted future net cash flows

 

$

45,263

 

$

18,310

 

 

The principle sources of change in the standardized measure of discounted future net cash flows are (in thousands):

 

 

 

For the Years Ended
December 31,

 

 

 

2015

 

2014

 

Balance at beginning of year

 

$

18,310

 

$

 

Sales of crude oil and natural gas

 

(2,119

)

(65

)

Net change in prices and production costs

 

(13,935

)

 

Net changes in future development costs

 

1

 

 

Extensions, discoveries, and other additions

 

38,442

 

18,478

 

Revision of previous quantity estimates

 

(3,612

)

 

Previously estimated development costs incurred

 

7,000

 

 

Net change in income taxes

 

(499

)

(92

)

Accretion of discount

 

1,840

 

 

Other

 

(165

)

(11

)

Balance at end of year

 

$

45,263

 

$

18,310

 

 

Note 12 - Events Subsequent to March 16, 2016

 

In June 2016, the Company and an affiliate of a stockholder (“Stockholder Affiliate”) entered into a services agreement whereby the Company will be charged up to $2,450 per day of services provided to the Company by a group of employees of the Stockholder Affiliate.  This agreement can be terminated with 10 days’ notice.

 

24



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 12 - Events Subsequent to March 16, 2016 (continued)

 

In June 2016, the Company and an investee company of a stockholder (“Stockholder Investee Company”) entered into a services agreement whereby the Company may charge the Stockholder Investee Company up to $6,850 per day of services provided to the Stockholder Investee Company by a group of employees of the Company.  This agreement can be terminated with 10 days’ notice.

 

In July 2016, the Company entered into a senior revolving line-of-credit (the “Credit Agreement”) with Texas Capital Bank with a maximum commitment of $100,000,000. The Credit Agreement has an initial borrowing base of $20,000,000, which is subject to semi-annual redeterminations. Repayment of borrowings is required in the event that the redetermined borrowing base is less than outstanding borrowings or on the maturity date in July 2020. Interest accrues at either the Alternate Base Rate or LIBOR plus applicable margins ranging 2.00% to 4.00% based upon the borrowing base usage. The Company pays a commitment fee of 0.50% of the unused borrowing base. Amounts borrowed under the Credit Agreement are collateralized by substantially all of the Company’s assets. As of September 2, 2016, the outstanding amount of borrowings under this Credit Agreement was $20,000,000. The Credit Agreement restricts the Company’s ability to, among other items, incur additional indebtedness, sell assets, pay dividends; and requires the Company to enter into swaps, puts, or collars representing between 75% and 85% of projected proved developed producing volumes. The Credit Agreement contains certain financial covenants, including but not limited to, a maximum senior debt to EBITDAX (as defined in the Credit Agreement) ratio, a minimum current ratio, and a minimum interest coverage ratio.

 

In July 2016, the Company entered into one oil costless collar and one natural gas costless collar, details of which are as follows:

 

Commodity

 

Settlement
Month

 

Volumes

 

Floor
(Purchased Put)

Price

 

Ceiling (Sold
Call) Price

 

Oil — WTI

 

August 2016

 

34,272 Bbls

 

$

42.00

 

$

45.75

 

Oil — WTI

 

September 2016

 

37,551 Bbls

 

$

42.00

 

$

45.75

 

Oil — WTI

 

October 2016

 

33,810 Bbls

 

$

42.00

 

$

45.75

 

Oil — WTI

 

November 2016

 

30,926 Bbls

 

$

42.00

 

$

45.75

 

Oil — WTI

 

December 2016

 

29,093 Bbls

 

$

42.00

 

$

45.75

 

Natural Gas — Henry Hub

 

August 2016

 

157,065 Mcf

 

$

2.10

 

$

3.65

 

Natural Gas — Henry Hub

 

September 2016

 

266,876 Mcf

 

$

2.10

 

$

3.65

 

Natural Gas — Henry Hub

 

October 2016

 

251,654 Mcf

 

$

2.10

 

$

3.65

 

Natural Gas — Henry Hub

 

November 2016

 

234,892 Mcf

 

$

2.10

 

$

3.65

 

Natural Gas — Henry Hub

 

December 2016

 

215,413 Mcf

 

$

2.10

 

$

3.65

 

 

On August 5, 2016, the Company acquired approximately 655 net acres (the “Acquired Acreage”) and interests in three well bores in exchange for $10.5 million and interests in certain acreage and surface interests. If the Company or its successor sells the Acquired Acreage within one year, the Company or its successor is obligated to pay additional consideration equal to 50% of the amount that exceeds a value of $11,000 per net acre.

 

25



 

ARRIS PETROLEUM CORPORATION

 

Notes to Consolidated Financial Statements

 

Note 12 - Events Subsequent to March 16, 2016 (continued)

 

On August 23, 2016, the Company entered into a stock purchase agreement with PDC Energy, Inc. with an effective date of July 1, 2016 (the “Sale Agreement”).  The Sale Agreement calls for payments in both privately placed stock and cash and is expected to close in the fourth quarter of 2016.  The purchase price for 100% of the Company’s stock was valued at $864 million.

 

26



 

Arris Petroleum Corporation

 

Unaudited Consolidated Balance Sheets

as of June 30, 2016 and Audited Consolidated Balance Sheet as of December 31, 2015

 

and

 

Unaudited Consolidated Statements of Operations and Changes in Cash Flows

for the Six Month Periods Ended June 30, 2016 and 2015

 

and

 

Unaudited Condensed Changes in Stockholders’ Deficit

for the Six Month Period Ended June 30, 2016

 



 

ARRIS PETROLEUM CORPORATION

 

Consolidated Balance Sheets

 

 

 

June 30,

 

December 31,

 

 

 

2016

 

2015

 

 

 

(Unaudited)

 

 

 

 

 

 

 

 

 

Assets

 

 

 

 

 

 

 

 

 

 

 

Current assets

 

 

 

 

 

Cash and equivalents

 

$

1,294,354

 

$

3,720,366

 

Revenue receivable

 

4,430,177

 

660,452

 

JIB receivable

 

249,162

 

1,277,575

 

Due from stockholder

 

 

5,167,774

 

Affiliate receivable

 

32,106

 

 

Other current assets

 

266,109

 

414,726

 

Total current assets

 

6,271,908

 

11,240,893

 

 

 

 

 

 

 

Property and equipment

 

 

 

 

 

Oil and gas properties (successful efforts method)

 

 

 

 

 

Proved properties

 

117,594,525

 

76,050,422

 

Unproved properties

 

51,571,119

 

58,904,693

 

Other property and equipment

 

632,576

 

608,217

 

Accumulated depreciation, depletion, and amortization

 

(14,321,291

)

(5,552,375

)

Property and equipment, net

 

155,476,929

 

130,010,957

 

 

 

 

 

 

 

Total assets

 

$

161,748,837

 

$

141,251,850

 

 

 

 

 

 

 

Liabilities and Stockholders’ Deficit

 

 

 

 

 

 

 

 

 

 

 

Current liabilities

 

 

 

 

 

Trade payables

 

$

10,452,283

 

$

15,800,636

 

Accrued liabilities

 

1,722,388

 

5,749,725

 

Revenue payable

 

2,156,338

 

421,064

 

Total current liabilities

 

14,331,009

 

21,971,425

 

 

 

 

 

 

 

Asset retirement obligations

 

1,039,444

 

689,292

 

Total liabilities

 

15,370,453

 

22,660,717

 

 

 

 

 

 

 

Redeemable Convertible Senior Preferred Stock, $0.001 par value, 325,000 shares authorized, 207,182 (2016) and 175,043 (2015) shares issued and outstanding, liquidation preference of $233,086,435 (2016) and $192,218,143 (2015)

 

233,086,435

 

192,218,143

 

 

 

 

 

 

 

Commitments and contingencies

 

 

 

 

 

 

 

 

 

 

 

Stockholders’ deficit

 

 

 

 

 

Class A and Class B Common Stock, $0.001 par value, 210,000 shares authorized, 161,675 (2016 and 2015) shares issued and outstanding

 

162

 

162

 

Additional paid-in capital

 

(26,279,551

)

(17,549,895

)

Accumulated deficit

 

(60,428,662

)

(56,077,277

)

Total stockholders’ deficit

 

(86,708,051

)

(73,627,010

)

 

 

 

 

 

 

Total liabilities and stockholders’ deficit

 

$

161,748,837

 

$

141,251,850

 

 

28



 

ARRIS PETROLEUM CORPORATION

 

Condensed Consolidated Statements of Operations (Unaudited)

 

 

 

Six Months Ended

 

 

 

June 30,

 

 

 

2016

 

2015

 

 

 

 

 

 

 

Revenues

 

 

 

 

 

Oil revenues

 

$

7,616,977

 

$

327,337

 

Gas and natural gas liquids revenues

 

1,338,890

 

464,835

 

Total oil and gas revenues

 

8,955,867

 

792,172

 

 

 

 

 

 

 

Other revenue

 

6,756

 

 

Total revenues

 

8,962,623

 

792,172

 

 

 

 

 

 

 

Operating expenses

 

 

 

 

 

Lease operating expenses

 

1,502,197

 

451,350

 

Production taxes

 

427,961

 

51,117

 

Depreciation, depletion, amortization, and accretion

 

8,792,106

 

1,876,033

 

Workover expense

 

112,276

 

5,030

 

Geological and geophysical

 

1,802

 

1,262,559

 

General and administrative expense

 

2,480,269

 

2,299,589

 

Total operating expenses

 

13,316,611

 

5,945,678

 

 

 

 

 

 

 

Other income

 

 

 

 

 

Interest and dividend income

 

2,595

 

5,781

 

Other income

 

8

 

 

Total other income

 

2,603

 

5,781

 

 

 

 

 

 

 

Net loss

 

$

(4,351,385

)

$

(5,147,725

)

 

29



 

ARRIS PETROLEUM CORPORATION

 

Condensed Consolidated Statement of Changes in Stockholders’ Deficit (Unaudited)

 

 

 

 

 

 

 

 

 

 

 

Additional

 

 

 

Total

 

 

 

Class A Common Stock

 

Class B Common Stock

 

Paid-In

 

Accumulated

 

Stockholders’

 

 

 

Shares

 

Amount

 

Shares

 

Amount

 

Capital

 

Deficit

 

Deficit

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance - December 31, 2015

 

159,797

 

$

160

 

1,878

 

$

2

 

$

(17,549,895

)

$

(56,077,277

)

$

(73,627,010

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other

 

 

 

 

 

(151

)

 

(151

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Accrued dividends on Redeemable Convertible Senior Preferred Stock

 

 

 

 

 

(8,729,505

)

 

(8,729,505

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net loss

 

 

 

 

 

 

(4,351,385

)

(4,351,385

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance - June 30, 2016

 

159,797

 

$

 

160

 

1,878

 

$

2

 

$

(26,279,551

)

$

(60,428,662

)

$

(86,708,051

)

 

30



 

ARRIS PETROLEUM CORPORATION

 

Condensed Consolidated Statements of Changes in Cash Flows (Unaudited)

 

 

 

Six Months Ended

 

 

 

June 30,

 

 

 

2016

 

2015

 

 

 

 

 

 

 

Cash flows from operating activities

 

 

 

 

 

Net loss

 

$

(4,351,385

)

$

(5,147,725

)

Adjustments to reconcile net loss to net cash provided by (used in) operating activities

 

 

 

 

 

Depreciation, depletion, amortization, and accretion

 

8,792,106

 

1,876,033

 

Changes in operating assets and liabilities

 

 

 

 

 

Accounts receivable

 

(2,741,312

)

79,836

 

Affiliate receivable

 

(32,106

)

 

Other current assets

 

148,617

 

74,668

 

Accounts payable and accrued liabilities

 

(1,746,900

)

135,501

 

Oil and gas revenue payable

 

1,735,274

 

1,558

 

 

 

6,155,679

 

2,167,596

 

 

 

 

 

 

 

Net cash provided by (used in) operating activities

 

1,804,294

 

(2,980,129

)

 

 

 

 

 

 

Cash flows from investing activities

 

 

 

 

 

Investment in oil and gas properties

 

(41,512,357

)

(28,531,315

)

Acquisition of oil and gas properties

 

 

(4,760,000

)

Purchase of furniture and equipment

 

(24,359

)

(29,563

)

Net cash used in investing activities

 

(41,536,716

)

(33,320,878

)

Cash flows from financing activities

 

 

 

 

 

Proceeds from issuance of common stock

 

 

1,878

 

Proceeds from issuance of Redeemable Convertible Senior Preferred Stock

 

37,306,561

 

20,768,065

 

Redemption of Redeemable Convertible Preferred Stock

 

 

(830,712

)

Redemption of common stock

 

 

(14,538

)

Other

 

(151

)

 

Net cash provided by financing activities

 

37,306,410

 

19,924,693

 

 

 

 

 

 

 

Net decrease in cash and cash equivalents

 

(2,426,012

)

(16,376,314

)

 

 

 

 

 

 

Cash and cash equivalents - beginning of year

 

3,720,366

 

23,549,819

 

 

 

 

 

 

 

Cash and cash equivalents - end of year

 

$

1,294,354

 

$

7,173,505

 

Supplemental disclosure of non-cash activity:

 

 

 

 

 

Current liabilities related to oil and gas property additions

 

$

11,380,208

 

$

1,173,537

 

Capitalized asset retirement obligations

 

$

326,962

 

$

143,567

 

Acquired asset retirement obligations

 

$

 

$

272,022

 

Accrued Redeemable Convertible Senior Preferred Stock dividends

 

$

8,729,505

 

$

4,651,356

 

 

31


 


 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Note 1 - Description of Business and Summary of Significant Accounting Policies

 

Arris Petroleum Corporation (the “Company”) is an independent energy company with substantially all of its producing oil and gas property located in the Permian Basin.

 

The Company was formed in the state of Delaware on October 16, 2013 with the purpose of acquiring and developing oil and gas properties located in the United States and commenced substantial operations in 2014.

 

Interim Financial Information

 

In the Company’s opinion, the accompanying consolidated financial statements contain all adjustments (consisting of only normal recurring adjustments) necessary for a fair statement of our financial statements for interim periods in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”). Accordingly, certain notes and other financial information included in audited financial statements have been condensed or omitted. The information presented in these interim period financial statements should be read in conjunction with the Company’s audited consolidated financial statements and notes thereto for the year ended December 31, 2015. Results of operations and cash flows for the six months ended June 30, 2016 are not necessarily indicative of the results to be expected for the full year or any other future period.

 

Principles of Consolidation

 

The accompanying consolidated financial statements include the accounts of Arris Petroleum Corporation and its wholly owned subsidiaries, Arris Operating Company, LLC; Arris Delaware Basin, LLC; Kimmeridge West Texas, LLC; and Arris Reeves Infrastructure, LLC. All intercompany accounts and transactions have been eliminated in consolidation.

 

Use of Estimates

 

The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures 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. Actual results could differ from those estimates.

 

The impact of oil and gas prices has a significant influence on estimates made by management. Changes in oil and gas prices directly affect the economic limits of estimated oil and gas reserves. These economic limits have significant effects upon estimated reserve quantities and valuations. These estimates are the basis for the calculation of depreciation, depletion, and amortization for the oil and gas properties and the assessment as to whether an impairment of such properties is required. In addition, significant estimates include the estimated cost and timing related to asset retirement obligations and the recoverability of unproved properties.

 

Cash and Cash Equivalents

 

The Company considers all highly liquid instruments purchased with an original maturity of three

 

32



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

months or less to be cash equivalents. The Company continually monitors its positions with, and the credit quality of, the financial institutions with which it invests. As of the balance sheet date, and periodically throughout the year, the Company has maintained balances in various operating accounts in excess of federally insured limits.

 

Accounts Receivable

 

The Company accrues for oil and gas sales based on actual production dates. Joint interest billings represent monthly billings to working interest owners in the properties the Company operates. These receivables are due within 30 days of billing, with a right of offset against revenues due to working interest owners in the properties. No interest is charged on past-due balances. All receivables are reviewed periodically, and appropriate actions are taken on past-due amounts, if any.

 

33



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Note 1 - Description of Business and Summary of Significant Accounting Policies (continued)

 

Concentrations of Credit Risk

 

The Company grants credit in the normal course of business to oil and gas purchasers in the United States. Collectibility of the Company’s oil and gas sales is dependent upon the financial condition of the Company’s purchasers as well as general economic conditions of the industry. As of and for the six months ended June 30, 2016, three purchasers accounted for 97% of oil and gas sales and two purchasers accounted for 97% of revenue receivable.  For the six months ended June 30, 2015, three purchasers accounted for 100% of oil and gas sales.

 

Accounting for Oil and Gas Properties

 

The Company follows the successful efforts method of accounting for its oil and gas properties. The Company does not capitalize general and administrative expenses directly identifiable with such activities. Costs of unsuccessful exploration efforts are expensed in the period it is determined that such costs are not recoverable through future net revenues. Geological and geophysical costs and delay rentals are expensed as incurred. The cost of development wells are capitalized whether productive or non-productive. Upon the sale of proved properties, the cost and accumulated depletion are removed from the accounts, and any gain or loss is reflected in the consolidated statement of operations. If it is determined that the sale of proved properties did not significantly affect the units-of-production depletion rate, the sale is treated as a normal retirement with no gain or loss recognized.

 

Capitalized costs for unproved oil and gas properties are assessed at least annually to determine if an impairment in value needs to be recognized. There were no unproved property impairments during the six months ended June 30, 2016 and the year ended December 31, 2015. For sales of partial interests in unproved properties, the Company treats the proceeds as a recovery of costs with no gain recognized until all costs have been recovered. During the year ended December 31, 2015 the Company recognized a loss of $733,000, related to the sales of an entire interest in unproved properties. No sales of unproved properties occurred during the six months ended June 30, 2016.

 

34



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Note 1 - Description of Business and Summary of Significant Accounting Policies (continued)

 

Accounting for Oil and Gas Properties (continued)

 

Depreciation, depletion, and amortization of proved oil and gas properties is calculated using the units-of-production method based on proved reserves and estimated salvage values.  For the six months ended June 30, 2016 and 2015, depletion expense was approximately $8,685,506 and $1,841,630, respectively.

 

The Company assesses the recoverability of its capitalized costs for its proved oil and gas properties periodically, or when circumstances indicate there is a need for such review. To determine if a depletable unit (generally defined as an individual field) is impaired, the Company compares the carrying value of the depletable unit to the undiscounted future net cash flows by applying estimated future prices over the economic lives of the reserves. For each depletable unit determined to be impaired, an impairment loss equal to the difference between the carrying value and the estimated fair value of the depletable unit will be recognized. Fair value, on a depletable unit basis, is estimated to be the present value of expected future cash flows computed by applying estimated future oil and gas prices, as determined by management, to estimated future production of oil and gas reserves over the economic lives of the reserves and the application of a discount rate commensurate with the risk associated with realizing the expected cash flows. The discount rate is a rate that management believes is representative of current market conditions and includes estimates for the risk premium. Due to low oil and gas prices, the Company recorded proved property impairments of $38,661,606 during the fourth quarter of 2015.  No proved property impairments were recorded during the three and six months ended June 30, 2016.

 

35



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Note 1 - Description of Business and Summary of Significant Accounting Policies (continued)

 

Property and Equipment

 

Property and equipment are stated at cost. Depreciation is provided utilizing the straight-line method over the estimated useful lives for owned assets, ranging from five to seven years.

 

Revenue Recognition

 

Natural gas revenues are recognized when the title and risk pass to the purchaser. The Company records its share of revenues based on its share of proceeds. The Company sells the majority of its products soon after production at various locations, including the wellhead, at which time title and risk of loss pass to the buyer.

 

Gas imbalances occur when the Company sells more or less than its entitled ownership percentage of total gas production. Any amount received in excess of the Company’s share is treated as a liability. If the Company receives less than its entitled share, the underproduction is recorded as a receivable.

 

At June 30, 2016 and December 31, 2015, the Company did not have any material gas imbalances.

 

Oil revenues are recognized when production is sold to a purchaser at a fixed or determinable price, delivery has occurred, title is transferred, and collectibility is assured.

 

Income Taxes

 

The Company recognizes deferred tax liabilities and assets based on the differences between the tax basis of assets and liabilities and their reported amounts in the consolidated financial statements that will result in taxable or deductible amounts in future years. The Company’s temporary differences result primarily from depletion and impairments of oil and gas properties under the successful efforts method of accounting.

 

The Company’s deferred income taxes include certain future tax benefits. The Company records a valuation allowance against any portion of those deferred income tax assets when it believes, based on the weight of available evidence, it is more likely than not that some portion or all of the deferred income tax asset will not be realized.

 

The Company evaluates its tax positions taken or expected to be taken in the course of preparing the Company’s tax returns to determine whether the tax positions will more likely than not be sustained by the applicable tax authority. Tax positions not deemed to meet the more-likely-than-not threshold are not recorded as a tax benefit or expense in the current year. Interest and penalties, if applicable, are recorded in the period assessed as general and administrative expenses. However, no interest or penalties have been assessed for the six months ended June 30, 2016 and 2015 and the year ended December 31, 2015.

 

36



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Note 1 - Description of Business and Summary of Significant Accounting Policies (continued)

 

Stock-Based Compensation

 

The Company recognizes compensation expense for stock-based awards when all performance and service conditions are probable of being satisfied (generally upon a liquidation event).

 

Note 2 - Acquisitions and Divestitures

 

In June 2015, the Company entered into a purchase and sale agreement with an unrelated party to acquire the right, title, and interest in and to several oil and gas properties totaling $4,760,000. The Company recorded the estimated fair value of the identifiable assets acquired as of the acquisition date.

 

See below for a summary of the assets acquired and liabilities assumed with this transaction:

 

Purchase price

 

 

 

Cash consideration

 

$

4,760,000

 

 

 

 

 

Recognized amounts of identifiable assets and liabilities acquired

 

 

 

Proved oil and gas properties

 

$

3,561,922

 

Pipeline and gas gathering equipment

 

951,575

 

Unproved properties

 

518,525

 

Asset retirement obligation assumed

 

(272,022

)

Total identifiable net assets

 

$

4,760,000

 

 

37



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Note 2 - Acquisitions and Divestitures (continued)

 

To determine the fair value of the proved oil and gas properties acquired in the business combination, the Company used an income approach based on a discounted cash flow model and made market assumptions as to future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development and operating costs, projections of future rates of production, expected recovery rates, and risk-adjusted discount rates. The Company determined the appropriate discount rates used for the discounted cash flow analyses by using a weighted-average cost of capital from a market participant perspective plus property-specific risk premiums for the assets acquired. The pipeline and gas gathering equipment acquired is included in proved oil and gas properties and is subject to units-of-production depletion and impairment at the depletable unit.

 

In December 2015, the Company entered into a purchase and sale agreement with an unrelated party to divest certain unproved oil and gas properties. The properties were sold for $1,426,000 in cash, resulting in a loss of $733,000.

 

Note 3 - Fair Value Measurements

 

The Company applies the authoritative guidance applicable to all financial assets and liabilities required to be measured and reported at fair value on a recurring basis, as well as to non-financial assets and liabilities measured at fair value on a non-recurring basis, including impairments of proved oil and gas properties and other long-lived assets and asset retirement obligations initially measured at fair value. The fair value of an asset or liability is the amount that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. The Company maximizes the use of observable inputs and minimizes the use of unobservable inputs when measuring fair value. Observable inputs are inputs that market participants would use in valuing the asset or liability based on market data obtained from sources independent of the Company. Unobservable inputs are inputs that reflect the Company’s assumptions of what market participants would use in valuing the asset or liability based on the best information available in the circumstances.

 

38



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Note 3 - Fair Value Measurements (continued)

 

Financial and non-financial assets and liabilities are classified within the valuation hierarchy based upon the lowest level of input that is significant to the fair value measurement. The Company’s policy is to recognize transfers in and out of the fair value hierarchy as of the end of the reporting period in which the event or change in circumstances caused the transfer. The hierarchy is organized into three levels based on the reliability of the inputs as follows:

 

Level 1:                        Quoted prices in active markets for identical assets or liabilities;

 

Level 2:                        Quoted prices in active markets for similar assets and liabilities and inputs, quoted prices for identical or similar assets or liabilities in markets that are not active, and model-derived valuations whose inputs or significant value drivers are observable; or

 

Level 3:                        Unobservable pricing inputs in which there is little or no market data, which requires the reporting entity to develop its own assumptions.

 

Recurring Fair Value Measurements

 

The Company did not have any assets or liabilities that were required to be measured at fair value on a recurring basis as of June 30, 2016 and December 31, 2015.

 

Non-Recurring Fair Value Measurements

 

The following table presents the Company’s non-financial assets and liabilities that were measured at fair value on a non-recurring basis during the period ended June 30, 2016 by level within the fair value hierarchy:

 

Description

 

Level 1

 

Level 2

 

Level 3

 

Total

 

Liability

 

 

 

 

 

 

 

 

 

Asset retirement obligations

 

$

 

$

 

$

326,962

 

$

326,962

 

 

The following table presents the Company’s non-financial assets and liabilities that were measured at fair value on a non-recurring basis during the year ended December 31, 2015 by level within the fair value hierarchy:

 

Description

 

Level 1

 

Level 2

 

Level 3

 

Total

 

Asset

 

 

 

 

 

 

 

 

 

Proved oil and gas properties:

 

 

 

 

 

 

 

 

 

Culberson field

 

$

 

$

 

$

9,799,797

 

$

9,799,797

 

Liability

 

 

 

 

 

 

 

 

 

Asset retirement obligations

 

$

 

$

 

$

363,084

 

$

363,084

 

 

39



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Note 3 - Fair Value Measurements (continued)

 

Non-Recurring Fair Value Measurements (continued)

 

Proved oil and gas properties are recorded at fair value if the carrying value exceeds undiscounted cash flows. The Company uses Level 3 inputs and the income valuation technique to measure the fair value of proved properties using discount rates and year-end commodity future prices selected by the Company’s management. The discount rate used was 10%, which is a rate that management believes is representative of current market conditions and includes estimates for the risk premium. The price forecast used for crude oil was the December 31, 2015 New York Mercantile (“NYMEX”) WTI price, adjusted for an estimated differential. The price forecast used for natural gas was the December 31, 2015 NYMEX Henry Hub price, adjusted for an estimated differential. During the year ended December 31, 2015, the Company valued its Culberson field at $9,799,797, which resulted in an impairment of $38,661,606. The impairment was driven primarily by the significant decline in commodity prices during the year ended December 31, 2015.

 

Fair value used in the initial recognition of asset retirement obligations and any subsequent upward changes in estimates is determined under the income approach using the present value of expected future remediation and dismantlement costs, incorporating the Company’s best estimate of inputs used by industry participants when valuing similar liabilities. Accordingly, the fair value is based on unobservable pricing inputs and, therefore, is considered a Level 3 measurement in the fair value hierarchy. During the period ended June 30, 2016 and the year ended December 31, 2015, the Company recorded asset retirement obligations of $326,962 and $363,084, respectively. See Note 4 for additional information.

 

Other assets and liabilities not measured at fair value on a recurring basis include cash and cash equivalents, accounts receivable, accounts payable, accrued liabilities, and revenue payable. The consolidated financial statement carrying amounts of these items approximate their fair values due to their short-term nature.

 

Note 4 - Asset Retirement Obligations

 

The Company follows the provisions of ASC Topic 410, Asset Retirement and Environmental Obligations . This topic requires that the fair value of a liability for an asset retirement obligation be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The associated asset retirement costs are capitalized as part of the carrying amount of the asset. The asset retirement obligations are allocated to operating expenses by using a systematic, rational method. The Company’s asset retirement obligations relate to the plugging and abandoning of its oil and gas wells and the reclamation of its well locations. The revisions made during the year ended December 31, 2015 were due to changes in estimated abandonment costs obtained by the Company based on current economic factors.

 

40



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Note 4 - Asset Retirement Obligations (continued)

 

A reconciliation of the changes in the Company’s liabilities are as follows:

 

 

 

For the Six
Months ended
June 30, 2016

 

For the Year
Ended
December 31,
2015

 

Beginning asset retirement obligations

 

$

689,292

 

$

45,680

 

Liabilities acquired

 

 

272,022

 

Liabilities incurred

 

326,962

 

219,517

 

Revisions

 

 

143,567

 

Accretion

 

23,190

 

8,506

 

 

 

 

 

 

 

Long-term asset retirement obligations

 

$

1,039,444

 

$

689,292

 

 

Note 5 - Commitments and Contingencies

 

Litigation

 

In the normal course of business, the Company is party to litigation from time to time. The Company maintains insurance to cover certain actions and believes that resolution of such litigation will not have a material adverse effect on the Company.

 

41



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Note 5 - Commitments and Contingencies (continued)

 

Shut-In Wells

 

In November 2015, the third-party gas plant servicing the Company’s wells in Culberson County was closed due to a gas processing plant explosion. As a result, those wells were shut-in temporarily pending the reopening of the plant.  The plant reopened during the second quarter of 2016.

 

42



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Note 6 - Redeemable Convertible Senior Preferred Stock

 

The Company is authorized to issue up to 350,000 preferred shares, par value $0.001. Of the 350,000 preferred shares authorized, the Company has designated 325,000 shares as Redeemable Convertible Senior Preferred Stock (“Senior Preferred Stock”). On January 14, 2016 and March 14, 2016, the Company issued an additional 21,000 shares and 11,139 shares, respectively, of Redeemable Convertible Preferred Stock for $1,000 per share.  As of June 30, 2016 and December 31, 2015, there were 207,182 and 175,043 shares of Senior Preferred Stock issued and outstanding, respectively, issued at an original issuance price of $1,000 per share (“Original Issue Price”).

 

During the year ended December 31, 2015, the Company redeemed 774 Senior Preferred shares for $773,772, plus the related cumulative preferred return of $56,946, as part of separation agreements entered into with certain members of management.

 

At December 31, 2015, the Company had $5,167,774 recorded as due from stockholders on the accompanying consolidated balance sheet relating to shares issued in December 2015. The balance of $5,167,774 was received by the Company on January 4, 2016.

 

Voting

 

The Senior Preferred Stock holders are entitled to vote as a separate class on certain matters, including (i) any amendment to the certificate of incorporation that would adversely affect the rights and preferences of Senior Preferred Stock; (ii) adoption of a Certification of Designation with respect to any series of preferred shares; (iii) any amendment to the Bylaws of the Company proposed by the holders of the Common Stock; and (iv) consummation by the Company of any contract for a liquidation event, as defined (“Liquidation Event”). In instances where both holders of Common Stock and Senior Preferred Stock have voting rights with respect to a matter for which a vote is being taken, holders will vote as separate classes. Approval of such matter will require majority approval of each voting class.

 

Conversion

 

Holders of the Senior Preferred Stock may elect to convert some or all of the Senior Preferred Stock within 30 days after the closing of an initial public offering (“IPO”) into the class of stock in the IPO at the IPO price.

 

Dividends

 

Holders of the Senior Preferred Stock are entitled to a cumulative preferred return of 8% per annum, compounded continually on the Adjusted Capital Balance with respect to such share through the earlier of (i) the redemption date of such share or (ii) a Liquidation Event, as defined. The Adjusted Capital Balance is defined as (i) the Original Issue Price, less (ii) the aggregate amount of all distributions made by the Company with respect to such share prior to such date, if any. As of June 30, 2016 and December 31, 2015, the Company recorded cumulative accrued Senior Preferred Stock dividends of $25,904,894 and $17,175,389, respectively.

 

43



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Note 6 - Redeemable Convertible Senior Preferred Stock (continued)

 

Liquidation

 

In the event of liquidation, dissolution, or winding up of the Company, the holders of the Senior Preferred Stock will be paid in cash for each share of Senior Preferred Stock held in an amount equal to the Original Issue Price, plus all accrued unpaid dividends (the “Liquidation Preference”), before any payment is made to any Common Stock holders. If the assets of the Company available for distribution to the holders of shares of the Senior Preferred Stock are insufficient to permit payment in full to such holders of the sums that such holders are entitled to receive in such case, then all of the assets available for distribution to holders of shares of the Senior Preferred Stock will be distributed among and paid to such holders ratably in proportion to the amounts that would be payable if such assets were sufficient to permit full payment.

 

Redemption

 

The Company may, but is not obligated to, redeem all or any portion of the Senior Preferred Stock at the Liquidation Preference. Upon a Liquidation Event, the Company is required to repurchase the Senior Preferred Stock with the proceeds received. Due to this conditional redemption feature, the Senior Preferred Stock has been classified outside of permanent equity.

 

Note 7 - Stockholders’ Deficit

 

The Company is authorized to issue up to 210,000 shares of Common Stock, par value $0.001, which is divided into two classes: Class A Common Stock (“Class A Stock”) and Class B Common Stock (“Class B Stock”) (collectively, “Common Stock”). There were 159,797 Class A Stock shares and 1,878 Class B Stock shares issued and outstanding as of June 30, 2016 and December 31, 2015. During the year ended December 31, 2015, the Company redeemed 11,768 Class A Stock shares and 2,770 Class B Stock shares for $1 per share as part of separation agreements entered into with certain members of management.

 

Voting

 

Each holder of Common Stock will be entitled to one vote for each share.

 

Conversion

 

Upon achievement of the Required Investor Return, each outstanding share of Class B Stock will be automatically converted into Class A Stock.

 

If, immediately prior to the effective date of an IPO, the Required Investor Return has not been achieved, all outstanding shares of Class B Stock will automatically convert into fractional shares of Class A Stock based upon the actual rate of return achieved through that date.

 

44



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Dividends

 

Holders of the Common Stock shall not be entitled to dividends until the Senior Preferred Stock has been redeemed at the Liquidation Preference and, after that, only when declared by the Board of Directors. When and if dividends are properly declared on the Common Stock:

 

a.          The holders of the outstanding shares of Class A Stock will be entitled to receive dividends with respect to each share of Class A Stock, prior to the payment of any dividend or other distribution on shares of Class B Stock, until a required investor return (“Required Investor Return”) has been achieved and paid in full.

 

b.          Once the Required Investor Return has been achieved and paid in full, the holders of all Common Stock will be entitled to receive all further dividends from the Company.

 

c.           Thereafter, all dividends with respect to shares of each class of Common Stock will be paid pro rata and in like matter to all of the holders entitled thereto.

 

Liquidation

 

In the event of liquidation, dissolution, or winding up of the Company, the assets of the Company legally available to the stockholders, after payment in full of the Liquidation Preference to the Senior Preferred Stock, will be distributed to the holders of Common Stock, first to the holders of Class A Stock, until the Required Investor Return has been achieved and paid in full. Once this is achieved, the holders of Common Stock will be entitled to all residual assets of the Company pro rata without limit.

 

Management Incentive Units

 

The Class B Stock is available to management only, and a portion of Class A Stock is also held by management (“Management Incentive Units”). The number of Class A Stock and Class B Stock shares held by management as of June 30, 2016 and December 31, 2015 was 7,990 and 1,879, respectively. The Management Incentive Units were purchased with cash at $1.00 per share and are generally subject to vesting over four years. If subsequent issuances of Class A Stock and Class B Stock occur, management is entitled to maintain their relative percentage of Class A Stock and Class B Stock without further consideration, subject to the original vesting schedule.

 

Note 8 - Income Taxes

 

The Company has pre-tax net operating loss carryforwards as of December 31, 2015 of $25,964,982, which expire before 2036. Internal Revenue Code Section 382 imposes limitations on a Company’s ability to recognize certain deferred tax assets upon a change of control of the Company. During 2014, the Company had a change of control event under Section 382, which will limit its ability to utilize its deferred tax assets, including net operating loss carryforwards, to offset future taxable income. The approximate amount of net operating losses subject to the Section 382 limitation is $650,000.

 

A valuation allowance is provided when it is more likely than not that all or some of the deferred income tax assets will not be realized. Based upon cumulative losses since inception and projections of future taxable income, the Company has recorded a valuation allowance of $21,306,031 at December

 

45



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

31, 2015.  During the three and six months ended June 30, 2016, the effective tax rate was zero due to the full valuation allowance on the deferred tax assets.  For the year ended December 31, 2016, the Company estimates the annual effective tax rate to be zero due to the full valuation allowance on the deferred tax assets.

 

The Company does not believe that it has any uncertain tax positions. It is the Company’s policy to recognize interest and penalties related to uncertain tax benefits in income tax expense.

 

Note 9 - Related Party Transactions

 

In June 2016, the Company and an affiliate of a stockholder (“Stockholder Affiliate”) entered into a services agreement whereby the Company will be charged up to $2,450 per day of services provided to the Company by a group of employees of the Stockholder Affiliate.  This agreement can be terminated with 10 days’ notice.

 

In June 2016, the Company and an investee company of a stockholder (“Stockholder Investee Company”) entered into a services agreement whereby the Company may charge the Stockholder Investee Company up to $6,850 per day of services provided to the Stockholder Investee Company by a group of employees of the Company.  This agreement can be terminated with 10 days’ notice.

 

Note 10 — Subsequent Events

 

In July 2016, the Company entered into a senior revolving line-of-credit (the “Credit Agreement”) with Texas Capital Bank with a maximum commitment of $100,000,000. The Credit Agreement has an initial borrowing base of $20,000,000, which is subject to semi-annual redeterminations. Repayment of borrowings is required in the event that the redetermined borrowing base is less than outstanding borrowings or on the maturity date in July 2020. Interest accrues at either the Alternate Base Rate or LIBOR plus applicable margins ranging 2.00% to 4.00% based upon the borrowing base usage. The Company pays a commitment fee of 0.50% of the unused borrowing base. Amounts borrowed under the Credit Agreement are collateralized by substantially all of the Company’s assets. As of September 2, 2016, the outstanding amount of borrowings under this Credit Agreement was $20,000,000. The Credit Agreement restricts the Company’s ability to, among other items, incur additional indebtedness, sell assets, pay dividends; and requires the Company to enter into swaps, puts, or collars representing between 75% and 85% of projected proved developed producing volumes. The Credit Agreement contains certain financial covenants, including but not limited to, a maximum senior debt to EBITDAX (as defined in the Credit Agreement) ratio, a minimum current ratio, and a minimum interest coverage ratio.

 

In July 2016, the Company entered into one oil costless collar and one natural gas costless collar, details of which are as follows:

 

46



 

ARRIS PETROLEUM CORPORATION

 

Notes to Condensed Consolidated Financial Statements (Unaudited)

 

Commodity

 

Settlement
Month

 

Volumes

 

Floor
(Purchased Put)
Price

 

Ceiling (Sold
Call) Price

 

Oil — WTI

 

August 2016

 

34,272 Bbls

 

$

42.00

 

$

45.75

 

Oil — WTI

 

September 2016

 

37,551 Bbls

 

$

42.00

 

$

45.75

 

Oil — WTI

 

October 2016

 

33,810 Bbls

 

$

42.00

 

$

45.75

 

Oil — WTI

 

November 2016

 

30,926 Bbls

 

$

42.00

 

$

45.75

 

Oil — WTI

 

December 2016

 

29,093 Bbls

 

$

42.00

 

$

45.75

 

Natural Gas — Henry Hub

 

August 2016

 

157,065 Mcf

 

$

2.10

 

$

3.65

 

Natural Gas — Henry Hub

 

September 2016

 

266,876 Mcf

 

$

2.10

 

$

3.65

 

Natural Gas — Henry Hub

 

October 2016

 

251,654 Mcf

 

$

2.10

 

$

3.65

 

Natural Gas — Henry Hub

 

November 2016

 

234,892 Mcf

 

$

2.10

 

$

3.65

 

Natural Gas — Henry Hub

 

December 2016

 

215,413 Mcf

 

$

2.10

 

$

3.65

 

 

On August 5, 2016, the Company acquired approximately 655 net acres (the “Acquired Acreage”) and interests in three well bores in exchange for $10.5 million and interests in certain acreage and surface interests. If the Company or its successor sells the Acquired Acreage within one year, the Company or its successor is obligated to pay additional consideration equal to 50% of the amount that exceeds a value of $11,000 per net acre.

 

On August 23, 2016, the Company entered into a stock purchase agreement with PDC Energy, Inc. with an effective date of July 1, 2016 (the “Sale Agreement”).  The Sale Agreement calls for payments in both privately placed stock and cash and is expected to close in the fourth quarter of 2016.  The purchase price for 100% of the Company’s stock was valued at $864 million.

 

47


Exhibit 99.2

 

PDC ENERGY, INC.

UNAUDITED PRO FORMA CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

 

INDEX

 

Financial Information

 

Page Number

 

 

 

Pro Forma Condensed Consolidated Balance Sheet as of June 30, 2016

 

2

Pro Forma Condensed Consolidated Statement of Operations for the Six Months Ended June 30, 2016

 

3

Pro Forma Condensed Consolidated Statement of Operations for the Year Ended December 31, 2015

 

4

Notes to Pro Forma Condensed Consolidated Financial Statements

 

5

 

1



 

PDC ENERGY, INC.

Pro Forma Condensed Consolidated Balance Sheet

(unaudited; in thousands, except share and per share data)

 

 

 

June 30, 2016

 

 

 

Historical

 

Arris
Petroleum

 

299 Sellers

 

Pro Forma
Adjustments (1)

 

Pro Forma

 

Assets

 

 

 

 

 

 

 

 

 

 

 

Current assets:

 

 

 

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

109,099

 

$

1,294

 

$

(389,411

)(a)

$

(525,265

)(b)

$

76,253

 

 

 

 

 

 

 

 

 

914,676

(c)

 

 

 

 

 

 

 

 

 

 

(10,250

)(f)

 

 

 

 

 

 

 

 

 

 

(5,890

)(g)

 

 

 

 

 

 

 

 

 

 

(18,000

)(h)

 

 

Other current assets

 

210,036

 

4,978

 

 

 

215,014

 

Total current assets

 

319,135

 

6,272

 

(389,411

)

355,271

 

291,267

 

Properties and equipment, net

 

1,930,595

 

155,477

 

639,000

(a)

867,000

(b)

3,846,090

 

 

 

 

 

 

 

 

 

400,396

(d)

 

 

 

 

 

 

 

 

 

 

(146,378

)(e)

 

 

Other assets

 

21,940

 

 

 

5,890

(g)

27,830

 

Total Assets

 

$

2,271,670

 

$

161,749

 

$

249,589

 

$

1,482,179

 

$

4,165,187

 

 

 

 

 

 

 

 

 

 

 

 

 

Liabilities and Equity

 

 

 

 

 

 

 

 

 

 

 

Liabilities

 

 

 

 

 

 

 

 

 

 

 

Current liabilities

 

$

187,199

 

$

14,331

 

$

 

$

914,676

(c)

$

1,098,206

 

 

 

 

 

 

 

 

 

(18,000

)(h)

 

 

Long-term debt

 

492,997

 

 

 

 

492,997

 

Deferred income taxes

 

41,133

 

 

 

400,396

(d)

441,529

 

Asset retirement obligations

 

81,583

 

1,040

 

1,000

(a)

 

83,623

 

Other liabilities

 

44,193

 

 

 

 

44,193

 

Total liabilities

 

847,105

 

15,371

 

1,000

 

1,297,072

 

2,160,548

 

 

 

 

 

 

 

 

 

 

 

 

 

Senior preferred stock

 

 

233,086

 

 

(233,086

)(e)

 

 

 

 

 

 

 

 

 

 

 

 

 

Equity

 

 

 

 

 

 

 

 

 

 

 

Shareholders’ equity:

 

 

 

 

 

 

 

 

 

 

 

Preferred shares, par value $0.01 per share; authorized 50,000,000 shares; issued: none

 

 

 

 

 

 

Common shares, par value $0.01 per share; authorized 100,000,000 shares; issued: 46,210,022

 

472

 

1

 

40

(a)

54

(b)

566

 

 

 

 

 

 

 

 

 

(1

)(e)

 

 

Additional paid-in capital

 

1,211,876

 

(26,280

)

248,549

(a)

341,681

(b)

1,802,106

 

 

 

 

 

 

 

 

 

26,280

(e)

 

 

Retained earnings

 

213,442

 

(60,429

)

 

60,429

(e)

203,192

 

 

 

 

 

 

 

 

 

(10,250

)(f)

 

 

Treasury shares, at cost: 20,836

 

(1,225

)

 

 

 

(1,225

)

Total shareholders’ equity

 

1,424,565

 

(86,708

)

248,589

 

418,193

 

2,004,639

 

Total Liabilities and Shareholders’ Equity

 

$

2,271,670

 

$

161,749

 

$

249,589

 

$

1,482,179

 

$

4,165,187

 

 


(1) See Note 4

 

See accompanying Notes to Pro Forma Condensed Consolidated Financial Statements

 

2



 

PDC ENERGY, INC.

Pro Forma Condensed Consolidated Statement of Operations

(unaudited; in thousands, except share and per share data)

 

 

 

Six Months Ended June 30, 2016

 

 

 

PDC Energy
Historical

 

Arris
Petroleum
Historical

 

Pro Forma
Adjustments (1)

 

PDC Energy
Pro Forma

 

Revenues:

 

 

 

 

 

 

 

 

 

Crude oil, natural gas and NGLs sales

 

$

186,208

 

$

8,956

 

$

 

$

195,164

 

Sales from natural gas marketing

 

4,050

 

 

 

4,050

 

Commodity price risk management loss, net

 

(81,745

)

 

 

(81,745

)

Well operations, pipeline income and other

 

2,415

 

7

 

 

2,422

 

Total revenues

 

110,928

 

8,963

 

 

119,891

 

 

 

 

 

 

 

 

 

 

 

Costs, expenses and other:

 

 

 

 

 

 

 

 

 

Lease operating expenses

 

29,005

 

1,615

 

 

30,620

 

Production taxes

 

10,114

 

428

 

 

10,542

 

Transportation, gathering and processing expenses

 

8,506

 

 

 

8,506

 

Cost of natural gas marketing

 

4,703

 

 

 

4,703

 

Exploration expense

 

447

 

2

 

 

449

 

Impairment of properties and equipment

 

5,171

 

 

 

5,171

 

General and administrative expense

 

46,358

 

2,480

 

 

48,838

 

Depreciation, depletion and amortization

 

204,402

 

8,769

 

 

213,171

 

Provision for uncollectible notes receivable

 

44,738

 

 

 

44,738

 

Accretion of asset retirement obligations

 

3,623

 

23

 

 

3,646

 

Loss on sale of properties and equipment

 

176

 

 

 

176

 

Total costs, expenses and other

 

357,243

 

13,317

 

 

370,560

 

 

 

 

 

 

 

 

 

 

 

Income (loss) from operations

 

(246,315

)

(4,354

)

 

(250,669

)

Interest expense

 

(22,566

)

 

(44,625

)(i)

(67,191

)

Interest income

 

1,735

 

3

 

 

1,738

 

 

 

 

 

 

 

 

 

 

 

Income (loss) before income taxes

 

(267,146

)

(4,351

)

(44,625

)

(316,122

)

Provision for income taxes

 

100,166

 

 

18,611

(j)

118,777

 

Net income (loss)

 

$

(166,980

)

$

(4,351

)

$

(26,014

)

$

(197,345

)

 

 

 

 

 

 

 

 

 

 

Earnings per share:

 

 

 

 

 

 

 

 

 

Basic

 

$

(3.78

)

 

 

 

 

$

(3.68

)

Diluted

 

$

(3.78

)

 

 

 

 

$

(3.68

)

 

 

 

 

 

 

 

 

 

 

Weighted-average common shares outstanding:

 

 

 

 

 

 

 

 

 

Basic

 

44,175

 

 

 

 

 

53,562

 

Diluted

 

44,175

 

 

 

 

 

53,562

 

 


(1) See Note 4

 

See accompanying Notes to Pro Forma Condensed Consolidated Financial Statements

 

3



 

PDC ENERGY, INC.

Pro Forma Condensed Consolidated Statement of Operations

(unaudited; in thousands, except share and per share data)

 

 

 

Year Ended December 31, 2015

 

 

 

PDC Energy
Historical

 

Arris
Petroleum
Historical

 

Pro Forma
Adjustments (1)

 

PDC Energy
Pro Forma

 

Revenues:

 

 

 

 

 

 

 

 

 

Crude oil, natural gas and NGLs sales

 

$

378,713

 

$

3,606

 

$

 

$

382,319

 

Sales from natural gas marketing

 

10,920

 

 

 

10,920

 

Commodity price risk management gain, net

 

203,183

 

 

 

203,183

 

Well operations, pipeline income and other

 

2,510

 

 

 

2,510

 

Total revenues

 

595,326

 

3,606

 

 

598,932

 

 

 

 

 

 

 

 

 

 

 

Costs, expenses and other:

 

 

 

 

 

 

 

 

 

Lease operating expenses

 

56,992

 

1,110

 

 

58,102

 

Production taxes

 

18,443

 

204

 

 

18,647

 

Transportation, gathering and processing expenses

 

10,151

 

174

 

 

10,325

 

Cost of natural gas marketing

 

11,717

 

 

 

11,717

 

Exploration expense

 

1,102

 

3,056

 

 

4,158

 

Impairment of properties and equipment

 

161,620

 

38,662

 

 

200,282

 

General and administrative expense

 

89,959

 

5,913

 

 

95,872

 

Depreciation, depletion and amortization

 

303,258

 

5,317

 

 

308,575

 

Accretion of asset retirement obligations

 

6,293

 

9

 

 

6,302

 

Gain (loss) on sale of properties and equipment

 

(385

)

733

 

 

348

 

Total costs, expenses and other

 

659,150

 

55,178

 

 

714,328

 

 

 

 

 

 

 

 

 

 

 

Loss from operations

 

(63,824

)

(51,572

)

 

(115,396

)

Interest expense

 

(47,571

)

 

(77,250

)(i)

(124,821

)

Interest income

 

4,807

 

10

 

 

4,817

 

 

 

 

 

 

 

 

 

 

 

Loss before income taxes

 

(106,588

)

(51,562

)

(77,250

)

(235,400

)

Provision for income taxes

 

38,308

 

 

48,949

(j)

87,257

 

Net loss

 

$

(68,280

)

$

(51,562

)

$

(28,301

)

$

(148,143

)

 

 

 

 

 

 

 

 

 

 

Earnings per share:

 

 

 

 

 

 

 

 

 

Basic

 

$

(1.74

)

 

 

 

 

$

(3.05

)

Diluted

 

$

(1.74

)

 

 

 

 

$

(3.05

)

 

 

 

 

 

 

 

 

 

 

Weighted-average common shares outstanding:

 

 

 

 

 

 

 

 

 

Basic

 

39,153

 

 

 

 

 

48,540

 

Diluted

 

39,153

 

 

 

 

 

48,540

 

 


(1) See Note 4

 

See accompanying Notes to Pro Forma Condensed Consolidated Financial Statements

 

4



 

Note 1 - Basis of Presentation

 

The unaudited pro forma condensed consolidated balance sheet of PDC Energy, Inc. (“PDC” or the “Company”) as of June 30, 2016, is derived from:

 

·                   the historical consolidated balance sheet of the Company;

 

·                   the historical consolidated balance sheet of Arris Petroleum Corporation (“Arris”); and

 

·                   the preliminary estimated values assigned to the identifiable assets to be acquired and liabilities to be assumed from 299 Resources, 299 Production, LLC, 299 Pipeline, LLC (collectively, “299 Sellers”)

 

The unaudited pro forma condensed consolidated statements of operations of the Company for the six months ended June 30, 2016 and year ended December 31, 2015 are derived from:

 

·                   the historical consolidated statements of operations of the Company; and

 

·                   the historical consolidated statements of operations of Arris.

 

The unaudited pro forma condensed consolidated balance sheet gives effect to the pending acquisition of the stock of Arris and the assets of 299 Sellers as if the transaction had occurred on June 30, 2016. The unaudited pro forma condensed consolidated statements of operations give effect to the acquisition of Arris and the issuance of the Company’s common shares as if the transactions had occurred on January 1, 2015. The transactions and the related adjustments are described in the accompanying notes to the financial statements. In the opinion of Company management, all adjustments have been made that are necessary to present fairly, in accordance with Regulation S-X of the Securities and Exchange Commission (“SEC”), the pro forma condensed consolidated financial statements.

 

The unaudited pro forma condensed consolidated balance sheet and statements of operations are presented for illustrative purposes only, and do not purport to be indicative of the results of operations that would actually have occurred if the transaction described had occurred as presented in such statements or that may be obtained in the future. In addition, future results may vary significantly from those reflected in such statements due to factors described in “Risk Factors” included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015 (the “2015 Form 10-K”), and elsewhere in the Company’s reports and filings with the SEC.

 

The financing of the acquisition in the pro forma financial statements assumes partial funding by a short-term financing agreement. The Company expects to repay amounts outstanding under the short-term financing with permanent financing, which is expected to include a combination of long-term debt and equity.

 

The unaudited pro forma condensed consolidated balance sheet and statements of operations should be read in conjunction with the Company’s historical consolidated financial statements and the notes thereto included in its 2015 Form 10-K. The pro forma statements should also be read in conjunction with the historical statements of Arris and the notes thereto filed as Exhibit 99.1 to the Current Report on Form 8-K of which this Exhibit 99.2 is a part.

 

Note 2 - Acquisition Date

 

The Company currently expects the acquisition to close in the fourth quarter of  2016, for an estimated closing price of approximately $1.5 billion, subject to customary closing conditions, including adjustments based on title and environmental due diligence, and would have an effective date of July 1, 2016. There can be no assurance the acquisition will close or the timing of any such closing.

 

5



 

PDC ENERGY, INC.

Notes To Pro Forma Condensed Consolidated Financial Statements

Six Months Ended June 30, 2016 And Year Ended December 31, 2015

(unaudited)

 

Note 3 - Preliminary Acquisition Accounting

 

The transaction is accounted for under the acquisition method of accounting. Accordingly, the Company conducts assessments of net assets acquired and liabilities assumed and recognizes amounts for identifiable assets acquired and liabilities assumed at their estimated acquisition date fair values, while transaction and integration costs associated with the acquisition are expensed as incurred. The preliminary purchase price allocation presented within is based on our initial assessment of the limited financial information available, pending final settlement and completion of valuation. The final purchase price allocation for the business combination will be performed subsequent to closing and adjustments to estimated amounts, or recognition of additional assets acquired or liabilities assumed, may occur as more detailed analyses are completed and additional information is obtained about the facts and circumstances that existed as of the acquisition date.

 

The following presents the preliminary estimated purchase price allocation of the net assets to be acquired in the pending acquisition (in thousands):

 

Assets:

 

 

 

Current Assets

 

$

6,272

 

Proved properties

 

91,000

 

Unproved properties

 

1,818,171

 

Other property and equipment

 

6,324

 

Total assets to be acquired

 

$

1,921,767

 

 

 

 

 

Liabilities:

 

 

 

Current liabilities

 

$

14,331

 

Asset retirement obligations

 

2,040

 

Deferred tax liabilities

 

400,396

 

Total liabilities to be assumed

 

416,767

 

Net assets to be acquired

 

$

1,505,000

 

 

 

 

 

 

The preliminary estimated fair value of properties and equipment and asset retirement obligations were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of properties and equipment include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; (iv) estimated future cash flows; and (v) a market-based weighted-average cost of capital rate.

 

Properties and Equipment. Significant accounting polices related to our properties and equipment are discussed below.

 

Crude Oil and Natural Gas Properties. We account for our crude oil and natural gas properties under the successful efforts method of accounting. Costs of proved developed producing properties, successful exploratory wells and developmental dry hole costs are capitalized and depreciated or depleted by the unit-of-production method based on estimated proved developed producing reserves. Property acquisition costs are depreciated or depleted on the unit-of-production method based on estimated proved reserves. We calculate quarterly depreciation, depletion and amortization (“DD&A”) expense by using our estimated prior period-end reserves as the denominator, with the exception of our fourth quarter where we use the year-end reserve estimate adjusted to add back fourth quarter production. Upon the sale or retirement of significant portions of or complete fields of depreciable or depletable property, the net book value thereof, less proceeds or salvage value, is recognized in the consolidated statements of operations as a gain or loss. Upon the sale of individual wells or a portion of a field, the proceeds are credited to accumulated DD&A.

 

6



 

PDC ENERGY, INC.

Notes To Pro Forma Condensed Consolidated Financial Statements

Six Months Ended June 30, 2016 And Year Ended December 31, 2015

(unaudited)

 

Proved Property Impairment. Upon a triggering event, we assess our producing crude oil and natural gas properties for possible impairment by comparing net capitalized costs, or carrying value, to estimated undiscounted future net cash flows on a field-by-field basis using estimated production based upon prices at which we reasonably estimate the commodity to be sold. The estimates of future prices may differ from current market prices of crude oil, natural gas and NGLs. Certain events, including but not limited to downward revisions in estimates to our reserve quantities, expectations of falling commodity prices or rising operating costs, could result in a triggering event and, therefore, a possible impairment of our proved crude oil and natural gas properties. If net capitalized costs exceed undiscounted future net cash flows, the measurement of impairment is based on estimated fair value utilizing a future discounted cash flows analysis and is measured by the amount by which the net capitalized costs exceed their fair value. Impairments are included in the consolidated statements of operations line item impairment of crude oil and natural gas properties, with a corresponding impact on accumulated DD&A on the consolidated balance sheets.

 

Unproved Property Impairment. The acquisition costs of unproved properties are capitalized when incurred, until such properties are transferred to proved properties or charged to expense when expired, impaired or amortized. Unproved crude oil and natural gas properties with individually significant acquisition costs are periodically assessed for impairment. Unproved crude oil and natural gas properties which are not individually significant are amortized, by field, based on our historical experience, acquisition dates and average lease terms. Impairment and amortization charges related to unproved crude oil and natural gas properties are charged to the consolidated statements of operations line item impairment of crude oil and natural gas properties.

 

Other Property and Equipment. Other property and equipment is carried at cost. Depreciation is provided principally on the straightline method over the assets’ estimated useful lives. We review these long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of the asset to estimated undiscounted future cash flows expected to be generated by the asset. If the carrying amount of the asset exceeds our estimated future cash flows, an impairment charge is recognized in the amount by which the carrying amount of the asset exceeds the fair value of the asset.

 

The following table presents the estimated useful lives of our other property and equipment:

 

Transportation and other equipment

 

3 - 20 years

 

Buildings

 

20 - 30 years

 

 

Maintenance and repair costs on other property and equipment are charged to expense as incurred. Major renewals and improvements are capitalized and depreciated over the remaining useful life of the asset. Upon the sale or other disposition of assets, the cost and related accumulated DD&A are removed from the accounts, the proceeds are applied thereto and any resulting gain or loss is reflected in income.

 

Note 4 - Pro Forma Adjustments

 

The pro forma condensed consolidated financial statements have been adjusted to reflect the estimated closing price to be paid by the Company for the stock of Arris and assets of 299 Sellers, estimated additional borrowings, issuance of Company stock to seller, adjustments to historical book values of Arris’ and 299 Sellers’ properties to their preliminary estimated fair values in accordance with the acquisition method of accounting and estimated direct acquisition costs, including to:

 

(a) reflect the consideration of $638.0 million, including cash paid of $389.4 million and 3,996,290 shares of Company stock valued at $248.6 million and the preliminary estimated fair value measurement of assets acquired from 299 Sellers and liabilities assumed for the acquisition;

 

7



 

PDC ENERGY, INC.

Notes To Pro Forma Condensed Consolidated Financial Statements

Six Months Ended June 30, 2016 And Year Ended December 31, 2015

(unaudited)

 

(b) reflect the consideration of $867.0 million, including cash paid of $525.3 million and 5,390,478 shares of Company stock valued at $341.7 million for the stock of Arris and adjustments to historical book value of the Arris assets to their preliminary estimated fair values in accordance with the acquisition method of accounting;

 

(c) reflect the assumed incremental draw on our existing credit facility of approximately $315.0 million and committed short-term financing of approximately $600.0 million incurred to partially fund the estimated closing price for Arris stock and 299 Sellers assets;

 

(d) record deferred tax liabilities of $421.7 million on the difference between the book basis and tax basis of Arris properties acquired as this was a non-taxable transaction due to no IRS section 338 election being made;

 

(e) eliminate Arris capital and adjust fair value of assets acquired;

 

(f) record estimated direct acquisition costs of $10.3 million;

 

(g) record estimated fees of $5.9 million paid to increase revolving credit facility commitment to $700.0 million;

 

(h) record estimated fees of $18.0 million for securing $600.0 million short-term financing;

 

(i) reflect interest payable and amortization of debt issuance costs for each period presented associated with a committed short-term financing and our existing credit facility incurred to partially fund the acquisition. The Company assumed it would utilize the short-term financing for the year ended December 31, 2015 and roll over the agreement through June 30, 2016 in accordance with terms included in the short-term financing agreement. The Company assumed a total of $34.4 million of debt issuance costs associated with short-term financing, which includes $10.5 million due if the short-term financing remains outstanding for more than one year, and an increase in the commitment under its existing credit facility. The Company assumed interest expense of $11.0 million and $19.1 million associated with amortization of debt issuance costs for the six months ended June 30, 2016 and year ended December 31, 2015, respectively. Interest expense of $33.6 million and $58.2 million was computed using effective interest rates of 9.75% and 8.25% for $600.0 million of short-term financing borrowings and estimated an interest rate of 2.75% for assumed borrowings of $315.0 million under its credit facility for the six months ended June 30, 2016 and year ended December 31, 2015, respectively. The assumptions above are for pro forma purposes only as the Company intends to replace the short-term financing with permanent financing, which is expected to include a combination of long-term debt and equity; and

 

(j) record the tax benefit on additional loss for the periods.

 

The pro forma condensed consolidated statements of operations also include an adjustment to the weighted-average common shares outstanding to reflect shares issued to fund the purchase price of the stock of Arris and the assets of 299 Sellers.

 

Note that the fair value of the proved properties and other property and equipment being acquired approximates the net book value and, as a result, no pro forma adjustment was made to DD&A expense for all periods presented as there would not be a significant change to DD&A expense.

 

The final structure and terms of the acquisition financing will be subject to market conditions and may change materially from the assumptions described above. Changes in the assumptions described above would result in changes to various components of the unaudited pro forma condensed consolidated balance sheet, including cash and cash equivalents, long-term debt and additional paid-in capital, and various components of the unaudited pro forma condensed consolidated statements of income, including interest expense, earnings per share and weighted-average shares outstanding. Depending upon the nature of the changes, the impact on the pro forma financial information could be material.

 

·                   The 9,386,768 shares of Company stock which will be issued was valued at approximately $63 per share for a total value of approximately $590.3 million. The following sets forth the increase or decreases to this value at the stock prices shown:

 

8



 

PDC ENERGY, INC.

Notes To Pro Forma Condensed Consolidated Financial Statements

Six Months Ended June 30, 2016 And Year Ended December 31, 2015

(unaudited)

 

Company
Stock Price

 

Value

 

Increase / (Decrease)

 

(per share)

 

(in thousands)

 

$

55

 

$

516,272

 

$

(74,052

)

60

 

563,206

 

(27,118

)

65

 

610,140

 

19,816

 

70

 

657,074

 

66,750

 

75

 

704,008

 

113,684

 

 

·                   For each $100 million of Company equity issued in lieu of borrowing under the short-term financing agreement, interest expense would decrease by approximately $4.9 million and $8.3 million for the six months ended June 30, 2016 and the year ended December 31, 2015, respectively;

 

·                   For each $100 million of Company equity issued in lieu of borrowing under its revolving credit facility, interest expense would decrease by approximately $1.4 million and $2.8 million for the six months ended June 30, 2016 and the year ended December 31, 2015, respectively;

 

·                   For each 0.25% increase in the assumed interest rates of the short-term financing borrowings and the credit facility borrowings, interest expense would increase by approximately $1.1 million and $2.3 million for the six months ended June 30, 2016 and the year ended December 31, 2015, respectively;

 

Note 5 - Supplemental Oil and Natural Gas Reserve Information

 

The following tables set forth certain unaudited pro forma information concerning the Company’s proved crude oil, natural gas and natural gas liquids (“NGLs”) reserves for the year December 31, 2015, giving effect to the acquisition of Arris 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. The estimates of reserves, and the standardized measure of future net cash flow, shown below, reflects Arris’ development plan for the Arris 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. Arris oil reserves include NGLs.

 

9



 

PDC ENERGY, INC.

Notes To Pro Forma Condensed Consolidated Financial Statements

Six Months Ended June 30, 2016 And Year Ended December 31, 2015

(unaudited)

 

 

 

PDC

 

 

 

PDC

 

 

 

PDC

 

PDC

 

 

 

Energy

 

Arris

 

Energy

 

Arris

 

Energy

 

Energy

 

 

 

Historical

 

Historical

 

Historical

 

Historical

 

Historical

 

Pro Forma

 

 

 

Crude Oil, Condensate

 

Natural Gas

 

NGLs

 

Total

 

 

 

(MBbls)

 

(MMcf)

 

(MBbls)

 

(MBoe)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Proved Reserves:

 

 

 

 

 

 

 

 

 

 

 

 

 

Proved reserves, December 31, 2014

 

100,515

 

547

 

536,972

 

3,486

 

60,119

 

251,257

 

Revisions of previous estimates

 

(43,268

)

(229

)

(154,775

)

853

 

(24,407

)

(93,558

)

Extension and discoveries

 

48,707

 

2,902

 

311,709

 

18,499

 

30,835

 

137,479

 

Purchases of reserves

 

17

 

 

215

 

 

23

 

76

 

Dispositions

 

(12

)

 

(82

)

 

(8

)

(34

)

Production

 

(6,984

)

(59

)

(33,302

)

(638

)

(2,835

)

(15,535

)

Proved reserves, December 31, 2015 (1)

 

98,975

 

3,161

 

660,737

 

22,200

 

63,727

 

279,685

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Proved developed reserves as of:

 

 

 

 

 

 

 

 

 

 

 

 

December 31, 2014

 

26,798

 

157

 

186,633

 

2,256

 

17,002

 

75,438

 

December 31, 2015 (1)

 

26,257

 

1,051

 

175,367

 

11,448

 

15,011

 

73,455

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Proved undeveloped reserves:

 

 

 

 

 

 

 

 

 

 

 

 

 

December 31, 2014

 

73,717

 

390

 

350,339

 

1,230

 

43,117

 

175,819

 

December 31, 2015 (1)

 

72,718

 

2,110

 

485,370

 

10,752

 

48,716

 

206,231

 

 

Standardized Measure of Discounted Future Net Cash Flows and Changes Therein Relating to Proved Reserves

 

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 acquisition of Arris properties. Future estimated cash flows were based on a 12-month average price calculated as the unweighted arithmetic average of the prices on the first day of each month, January through December applied to the year-end estimated proved reserves. Prices were adjusted by field for Btu content, transportation and regional price differences; however, they were not adjusted to reflect the value of commodity derivatives. Production and development costs were based on prices as of December 31, 2015. The amounts shown do not give effect to non-property related expenses, such as corporate general and administrative expenses, debt service or to depreciation, depletion and amortization expense. Production and development costs include those cash flows associated with the ultimate settlement of our asset retirement obligation. Future estimated income tax expense is computed by applying the statutory rate in effect at the end of each year to the future pretax net cash flows, less the tax basis of the properties and gives effect to permanent differences, tax credits and allowances related to the properties.

 

10



 

PDC ENERGY, INC.

Notes To Pro Forma Condensed Consolidated Financial Statements

Six Months Ended June 30, 2016 And Year Ended December 31, 2015

(unaudited)

 

Changes in the demand for crude oil, natural gas and NGLs, inflation, and other factors make such estimates inherently imprecise and subject to substantial revision. This table should not be construed to be an estimate of the current market value of the Company's proved reserves.

 

 

 

December 31, 2015

 

 

 

PDC

 

 

 

PDC

 

 

 

Energy

 

Arris

 

Energy

 

 

 

Historical

 

Historical

 

Pro Forma

 

 

 

(in thousands)

 

 

 

 

 

 

 

 

 

Future estimated revenues

 

$

6,297,298

 

$

202,923

 

$

6,500,221

 

Future estimated production costs

 

(1,577,393

)

(64,859

)

(1,642,252

)

Future estimated development costs

 

(1,952,332

)

(46,839

)

(1,999,171

)

Future estimated income tax expense

 

(508,332

)

(1,065

)

(509,397

)

Future net cash flows

 

2,259,241

 

90,160

 

2,349,401

 

10% annual discount for estimated timing of cash flows

 

(1,162,377

)

(44,897

)

(1,207,274

)

Standardized measure of discounted future net cash flows

 

$

1,096,864

 

$

45,263

 

$

1,142,127

 

 

 

 

 

 

 

 

 

Netted Back Prices Used to Estimate Reserves:

 

 

 

 

 

 

 

Oil (Bbl)

 

$

42.10

 

$

50.28

 

 

 

Natural gas (MMBtu)

 

$

2.05

 

2.59

 

 

 

NGLs (Bbl)

 

$

12.23

 

$

 

 

 

 

 

11



 

PDC ENERGY, INC.

Notes To Pro Forma Condensed Consolidated Financial Statements

Six Months Ended June 30, 2016 And Year Ended December 31, 2015

(unaudited)

 

The following table summarizes the principal sources of change in the standardized measure of discounted future net cash flows:

 

 

 

December 31, 2015

 

 

 

PDC

 

 

 

PDC

 

 

 

Energy

 

Arris

 

Energy

 

 

 

Historical

 

Historical

 

Pro Forma

 

 

 

(in thousands)

 

 

 

 

 

 

 

 

 

Sales of crude oil, natural gas and NGLs production, net of production costs

 

$

(293,127

)

$

(2,119

)

$

(295,246

)

Net changes in prices and production costs

 

(1,752,921

)

(13,935

)

(1,766,856

)

Extensions, discoveries and improved recovery, less related costs

 

489,178

 

38,442

 

527,620

 

Sales of reserves

 

(463

)

 

(463

)

Purchases of reserves

 

374

 

 

374

 

Development costs incurred during the period

 

368,840

 

7,000

 

375,840

 

Revisions of previous quantity estimates

 

(1,286,462

)

(3,612

)

(1,290,074

)

Changes in estimated income taxes

 

902,994

 

(499

)

902,495

 

Net changes in future development costs

 

112,958

 

1

 

112,959

 

Accretion of discount

 

345,007

 

1,840

 

346,847

 

Timing and other

 

(95,979

)

(165

)

(96,144

)

Total

 

$

(1,209,601

)

$

26,953

 

$

(1,182,648

)

 

It is necessary to emphasize that the data presented should not be viewed as representing the expected cash flow from, or current value of, existing proved reserves since the computations are based on a large number of estimates and arbitrary assumptions. Reserve quantities cannot be measured with precision and their estimation requires many judgmental determinations and frequent revisions. The required projection of production and related expenditures over time requires further estimates with respect to pipeline availability, rates of demand and governmental control. Actual future prices and costs are likely to be substantially different from the recent average prices and current costs utilized in the computation of reported amounts. Any analysis or evaluation of the reported amounts should give specific recognition to the computational methods utilized and the limitations inherent therein.

 

12