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): May 6, 2016
 

NORTHERN OIL AND GAS, INC.
(Exact name of Registrant as specified in its charter)
Minnesota
001-33999
95-3848122
(State or other jurisdiction
of incorporation)
(Commission File Number)
(IRS Employer
Identification No.)

315 Manitoba Avenue – Suite 200  
Wayzata, Minnesota
55391
(Address of principal executive offices)
(Zip Code)
Registrant’s telephone number, including area code   ( 952) 476-9800
 

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 (17CFR 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 May 6, 2016, Northern Oil and Gas, Inc. (the “Company”) entered into an amendment (the “Amendment”) to its third amended and restated credit agreement, dated February 28, 2012, as amended (the “Credit Agreement”), governing the Company’s revolving credit facility with Royal Bank of Canada, as Administrative Agent, and the lenders party thereto. Pursuant to the Amendment, the Company’s semi-annual borrowing base redetermination was completed and the borrowing base under the credit facility was reduced to $350 million. As of May 9, 2016, the Company had $117 million in outstanding borrowings under the credit facility, leaving $233 million of remaining availability. The next redetermination of the borrowing base is scheduled for October 1, 2016.

The Amendment also amends certain other provisions of the Credit Agreement, including to (i) reduce the minimum ratio of EBITDAX to interest expense that the Company is required to maintain (currently 2.5 to 1.0) beginning with the quarter ending December 31, 2016 and stepping down through the quarter ending March 31, 2018, (ii) increase by 50 basis points the interest rate paid on borrowings under the credit facility, and (iii) limit the Company’s ability to maintain excess cash liquidity without using it to reduce outstanding borrowings under the credit facility.

The Amendment is included as Exhibit 10.1 to this Form 8-K, and the foregoing description of the material terms of the Amendment is qualified by reference to such exhibit.


Item 2.02.     Results of Operations and Financial Condition .

On May 9, 2016, Northern Oil and Gas, Inc. issued a press release announcing 2016 first quarter financial and operating results. A copy of the press release is furnished as Exhibit 99.1 hereto.


Item 2.03.
Creation of a Direct Financial Obligation or an Obligation under an Off-Balance Sheet Arrangement of a Registrant .

The information set forth under Item 1.01 is hereby incorporated by reference into this Item 2.03.


Item 9.01.      Financial Statements and Exhibits .

Exhibit Number
 

Description
 
 
 
10.1
 
Eighth Amendment to Third Amended and Restated Credit Agreement, dated May 6, 2016, by and among Northern Oil and Gas, Inc., Royal Bank of Canada, and the Lenders party thereto.
99.1
 
Press release of Northern Oil and Gas, Inc., dated May 9, 2016.






SIGNATURES

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

Date: May 10, 2016
NORTHERN OIL AND GAS, INC.
By /s/ Erik J. Romslo                                  
Erik J. Romslo
Executive Vice President, General Counsel and Secretary







EXHIBIT INDEX

Exhibit Number
 

Description
 
 
 
10.1
 
Eighth Amendment to Third Amended and Restated Credit Agreement, dated May 6, 2016, by and among Northern Oil and Gas, Inc., Royal Bank of Canada, and the Lenders party thereto.
99.1
 
Press release of Northern Oil and Gas, Inc., dated May 9, 2016.

 


Exhibit 10.1
Execution Version




EIGHTH AMENDMENT
TO
THIRD AMENDED AND RESTATED CREDIT AGREEMENT

DATED AS OF MAY 6, 2016
AMONG
NORTHERN OIL AND GAS, INC.,
as Borrower ,
ROYAL BANK OF CANADA,
as Administrative Agent,
AND
THE LENDERS PARTY HERETO







EIGHTH AMENDMENT TO
THIRD AMENDED AND RESTATED CREDIT AGREEMENT
This EIGHTH AMENDMENT TO THIRD AMENDED AND RESTATED CREDIT AGREEMENT (this “ Amendment ”), dated as of May 6, 2016, is by and among Northern Oil and Gas, Inc., a Minnesota corporation (the “ Borrower ”), Royal Bank of Canada (the “ Administrative Agent ”), and the Lenders party hereto.
R E C I T A L S :
WHEREAS , the Borrower, the Administrative Agent and the other Lenders party thereto entered into that certain Third Amended and Restated Credit Agreement, dated as of February 28, 2012 (as previously amended by the First Amendment dated as of June 29, 2012, the Second Amendment dated as of September 28, 2012, the Third Amendment dated as of March 28, 2013, the Fourth Amendment dated as of September 30, 2013, the Fifth Amendment dated as of April 7, 2015, the Sixth Amendment dated as of May 13, 2015, the Seventh Amendment dated as of October 21, 2015 and as the same may be further amended, modified, supplemented or restated from time to time, the “ Credit Agreement ”);
WHEREAS , the Borrower has requested that the Administrative Agent and the Lenders amend the Credit Agreement as set forth below; and
WHEREAS , the Administrative Agent and the Lenders are willing to (i) amend the Credit Agreement and (ii) take such other actions as provided herein.
NOW, THEREFORE , in consideration of the premises and the mutual covenants contained herein and in the Credit Agreement, and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties hereto, intending to be legally bound, hereby agree as follows:
ARTICLE I
Definitions
Each capitalized term used in this Amendment and not defined herein shall have the meaning assigned to such term in the Credit Agreement.
ARTICLE II
Amendments to Credit Agreement

Section 2.01      Amendment to Section 1.02 of the Credit Agreement . Section 1.02 of the Credit Agreement is hereby amended by adding the following definitions where alphabetically appropriate:
Account Control Agreement ” shall mean, as to any deposit account or securities account of any Credit Party held with a financial institution, an agreement or agreements, in form and substance reasonably acceptable to the Administrative Agent, among such Credit





Party owning such deposit account or securities account, the Administrative Agent and the financial institution at which such deposit account or securities account is located, which agreement establishes the Administrative Agent’s control with respect to such deposit account. For purposes of this definition, the term “control” means “control” within the meaning of Article 9 of the UCC.
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.
Consolidated Cash Balance ” means, as of any date, the aggregate amount of cash and cash equivalents of the Credit Parties as of such date (other than Excluded Cash).
EEA Financial Institution ” means (a) any credit institution or investment firm 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 financial 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.
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.
Eighth Amendment Effective Date ” means May 6, 2016.
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.
Excluded Accounts ” means deposit accounts that are used solely for payroll funding, payroll taxes and other employee wage and benefit payments, tax payments or trust purposes.
Excluded Cash ” means, as of any date, (i) the aggregate amount of cash of the Credit Parties received as proceeds of any issuance by the Borrower of any Permitted Additional Debt or any issuance of Equity Interests by the Borrower; provided that in each such case prior to the permitted application thereof, such cash is deposited in a segregated

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deposit account that is subject to an Account Control Agreement, (ii) any cash set aside to pay royalty obligations of the Credit Parties then due and owing to third parties and for which the Credit Parties have issued checks or have initiated wires or ACH transfers in order to pay such amounts (or will issue checks or initiate wires or ACH transfers within five Business Days), (iii) any cash set aside to pay in the ordinary course of business, obligations of the Credit Parties (other than royalty obligations) then due and owing or that will become due and owing within five Business Days to third parties and for which the Credit Parties have issued checks or have initiated wires or ACH transfers in order to pay such amounts (or will issue checks or initiate wires or ACH transfers in order to pay such amounts within five Business Days) and (iv) any cash set aside to pay the purchase price in connection with acquisitions of the Credit Parties permitted under this Agreement then due and owing or that will become due and owing within five Business Days to third parties and for which (A) the Credit Parties have issued checks or have initiated wires or ACH transfers in order to pay such amounts (or will issue checks or initiate wires or ACH transfers in order to pay such amounts within five Business Days) and (B) the Borrower has delivered a certificate from a Responsible Officer to the Administrative Agent in form and substance reasonably satisfactory to the Administrative Agent, which such certificate shall include a summary of such acquisition, including, among other things, the purchase price and the third party buyer.
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.
Section 2.02      Amendment and Restatement of Definitions in Credit Agreement . The following definition contained in Section 1.02 of the Credit Agreement is hereby amended and restated to read in full as follows:
LIBO Rate ” means, with respect to any Eurodollar Borrowing for any Interest Period:

(a)    the rate of interest per annum, expressed on the basis of a year of 360 days, determined by the Administrative Agent, which is equal to the offered rate that appears on the page of the Reuters LIBOR01 screen (or any successor thereto as may be selected by the Administrative Agent) that displays an average British Bankers Association Interest Settlement Rate for deposits in dollars with a term equivalent to such Interest Period, determined as of approximately 11:00 a.m. (London time) two (2) business days prior to the first day of such Interest Period, or
(b)    if the rates referenced in the preceding subsection (a) are not available, the rate per annum determined by the Administrative Agent as the rate of interest, expressed on a basis of 360 days at which deposits in dollars for delivery on the first day of such Interest Period in same day funds in the approximate amount of the LIBO Rate loan being made, continued or converted by the Administrative Agent and with a term and amount comparable to such Interest Period and principal amount of such LIBO Rate loan as would be offered by the

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Administrative Agent’s London Branch to major banks in the offshore dollar market at their request at approximately 11:00 a.m. (London time) two (2) business days prior to the first day of such Interest Period;
provided that, if the rate determined based upon either clause (a) or (b) above is less than zero, such rate shall be deemed to be zero for purposes of this Agreement.
Section 2.03      Amendment to Definition of “Applicable Margin” . Section 1.02 of the Credit Agreement is hereby amended by replacing the Utilization Grid in the definition of “Applicable Margin” with the following:
Utilization Grid
Borrowing Base Utilization Percentage
<25%
25%
<50%
50%
<75%
75%
<90%
90%
Eurodollar Loans
2.00%
2.25%
2.50%
2.75%
3.00%
ABR Loans
1.00%
1.25%
1.50%
1.75%
2.00%

Section 2.04      Amendment to Definition of “Defaulting Lender” . Section 1.02 of the Credit Agreement is amended hereby by amending and restating clause (f) of the definition “Defaulting Lender” to read in full as follows:
“(f) (i) become the subject of a bankruptcy or insolvency proceeding, (ii) has had a receiver, conservator, administrator, trustee, custodian or similar Person appointed for it, (iii) has taken any action in furtherance of, or indicating its consent to, approval of or acquiescence in any such proceeding or appointment, (iv) become subject of a Bail-in Action, or (v) has a direct or indirect parent company that has become the subject of a bankruptcy or insolvency proceeding, or has had a receiver, conservator, administrator, trustee, custodian or similar Person appointed for it, or has taken any action in furtherance of, or indicating its consent to, approval of or acquiescence in any such proceeding or appointment or has become subject to a Bail-in Action; provided that a Lender shall not become a Defaulting Lender solely as the result of the acquisition or maintenance of an ownership interest in such Lender or its parent company, or the exercise of control over such Lender or its parent company, by a Governmental Authority, as long as such ownership interest or exercise of control does not result in or provide such Lender or its parent company with immunity from the jurisdiction of courts within the United States or from the enforcement of judgments or writs of attachment on its assets or permit such Lender or its parent company (or such Governmental Authority) to reject, repudiate, disavow or disaffirm any such Agreements made by such Lender or its parent company; provided further that the appointment of an administrator, provisional liquidator, conservator, receiver, trustee, custodian or other similar official by a supervisory authority or regulator with respect to a Lender or a Lender’s direct or indirect parent company under the Dutch Financial Supervision Act 2007 (as amended from time to time and including any successor legislation) shall not result in a Lender being deemed a Defaulting Lender.”

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Section 2.05      Amendment to Section 3.04 of the Credit Agreement . Section 3.04 of the Credit Agreement is hereby amended by adding a new clause (e) at the end of such Section to read in full as follows:
“(e)    If, as of the end of any Business Day, the Consolidated Cash Balance exceeds $15,000,000, then, within 5 Business Days of such date, the Borrower shall have prepaid Borrowings in an amount equal to the lesser of (x) the amount necessary to reduce the Consolidated Cash Balance to $15,000,000 and (y) the aggregate principal amount of all Borrowings outstanding at such time. Such prepayment will not result in the reduction of the Maximum Credit Amounts.”
Section 2.06      Amendments to Section 6.02 of the Credit Agreement . Section 6.02 of the Credit Agreement is hereby amended as follows:
(a)      by inserting a new section (g) thereof immediately following clause (f) thereof to read in full as follows:
“(g)    At the time of and immediately after giving effect to such Borrowing and the application of the proceeds thereof or the issuance, amendment, renewal or extension of such Letter of Credit, as applicable, the Consolidated Cash Balance shall not exceed an amount equal to $15,000,000.”
(b)      by amending and restating the final paragraph thereof to read in full as follows:
“Each request for a Borrowing and each request for the issuance, amendment, renewal or extension of any Letter of Credit shall be deemed to constitute a representation and warranty by the Borrower on the date thereof as to the matters specified in Sections 6.02(a) through (g) , except that the Borrower’s representation and warranty with respect to Section 6.02(d) shall be deemed to be to its knowledge.”
Section 2.07      Amendments to Article VII . Article VII of the Credit Agreement is hereby amended by adding new Section 7.32 thereto immediately after Section 7.31 thereof, which new Section 7.32 shall read in full as follows:
“Section 7.32     EEA Financial Institution . No Credit Party is an EEA Financial Institution.”
Section 2.08      Amendment to Article VIII of the Credit Agreement . Article VIII of the Credit Agreement is hereby amended by inserting new Section 8.19 thereof at the end of such article to read in full as follows:
“Section 8.19     Accounts . Each Credit Party shall:
(a) from and after the 30th day following the Eighth Amendment Effective Date (or such later date as may be extended by the Administrative Agent in its sole discretion from time to time), cause all of its deposit accounts and securities accounts, other than Excluded Accounts, to be subject to Account Control Agreements; and

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(b) upon the request of the Administrative Agent, promptly provide a schedule of the deposit accounts and securities accounts of the Credit Parties, together with such other information in respect of such accounts as the Administrative Agent may reasonably request.”
Section 2.09      Amendments to Section 9.01 of the Credit Agreement . Section 9.01(c) of the Credit Agreement is hereby amended and restated in its entirety to read as follows:
“(c)     Ratio of EBITDAX to Interest . The Borrower will not permit its ratio of EBITDAX to interest expense (determined in accordance with GAAP) for the four fiscal quarters then ended (i) as of the last day of the fiscal quarters ending on or after March 31, 2016 but prior to December 31, 2016, to be less than 2.5 to 1.00, (ii) as of the last day of the fiscal quarter ending on December 31, 2016, to be less than 1.75 to 1.00, (iii) as of the last day of the fiscal quarter ending on March 31, 2017, to be less than 1.5 to 1.00, (iv) as of the last day of the fiscal quarters ending on or after June 30, 2017 but prior to December 31, 2017, to be less than 1.25 to 1.00, (v) as of the last day of the fiscal quarters ending on or after December 31, 2017 but prior to June 30, 2018, to be less than 1.00 to 1.00 and (vi) as of the last day of the fiscal quarters ending on or after June 30, 2018, to be less than 2.5 to 1.00; provided however, if, in accordance with GAAP, the Borrower realizes any non-cash charges categorized as interest expense (including any such charges resulting from the accelerated realization of amortizing fees paid to the Administrative Agent or any Lender in connection with this Agreement in any given fiscal quarter as a result of a Borrowing Base reduction), then such non-cash charges shall be excluded from the calculation of interest expense for purposes of this Section 9.01(c) .”
Section 2.10      Amendment to Article XII of the Credit Agreement . Article XIV of the Credit Agreement is hereby amended by adding new Section 12.18 thereto immediately after Section 12.17 thereof, which new Section 12.18 shall read in full as follows:
“Section 12.18     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, to the extent such liability is unsecured, 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;

6



(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 undertaking, or a bridge institution that may be issued to it or otherwise conferred on it, and that such shares or other instruments of ownership will be accepted by it in lieu of any rights with respect to any such liability under this Agreement or any other Loan Document; or
(iii)    the variation of the terms of such liability in connection with the exercise of the write-down and conversion powers of any EEA Resolution Authority.”
ARTICLE III
Reaffirmation of the Borrowing Base

Section 3.01      Redetermination of the Borrowing Base . Notwithstanding the requirements of Section 2.07 of the Credit Agreement, effective as of the Eighth Amendment Effective Date, the amount of the Borrowing Base shall be reduced to $350,000,000.00, subject to further adjustments from time to time pursuant to Section 2.07, Section 8.13(c) or Section 9.12(d) of the Credit Agreement. The redetermination of the Borrowing Base pursuant to this Section 3.01 of this Amendment shall constitute the Scheduled Redetermination for April 1, 2016.
ARTICLE IV
Conditions Precedent

This Amendment shall become effective as of the date first referenced above when and only when the following conditions are satisfied (the “ Eighth Amendment Effective Date ”):
(a)      the Administrative Agent shall have received duly executed counterparts of this Amendment from the Borrower and the Lenders, in such numbers as the Administrative Agent or its counsel may reasonably request;
(b)      The Borrower shall have paid to the Administrative Agent, for the account of each Lender executing this Amendment, an amendment fee in an amount equal to 12.5 basis points (0.125%) of such Lender’s Applicable Percentage of the Borrowing Base after giving effect to this Amendment; and
(c)      the Administrative Agent and the Lenders shall have received all fees due and payable on or prior to the effectiveness hereof as provided in any Loan Document, including reimbursement or payment of all out-of-pocket expenses required to be reimbursed or paid by the Borrower under the Credit Agreement (including, without limitation, the reasonable fees and expenses of counsel to the Administrative Agent).

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ARTICLE V
Representations and Warranties

The Borrower hereby represents and warrants to the Administrative Agent and each Lender that:
(a)    Each of the representations and warranties made by the Borrower under the Credit Agreement and each other Loan Document is true and correct on and as of the actual date of execution of this Amendment by the Borrower, as if made on and as of such date, except for any representations and warranties made as of a specified date, which are true and correct as of such specified date.
(b)    At the time of, and immediately after giving effect to, this Amendment, no Default has occurred and is continuing.
(c)    The execution, delivery and performance by the Borrower of this Amendment have been duly authorized by the Borrower.
(d)    This Amendment constitutes the legal, valid and binding obligation of the Borrower, enforceable against the Borrower in accordance with its terms, subject to applicable bankruptcy, insolvency, reorganization, moratorium or other laws affecting creditors’ rights generally and subject to general principles of equity, regardless of whether considered in a proceeding in equity or at law.
(e)    The execution, delivery and performance by the Borrower of this Amendment (i) do not require any consent or approval of, registration or filing with, or any other action by, any Governmental Authority or any other third Person (including the members or any class of directors of the Borrower or any other Person, whether interested or disinterested), nor is any such consent, approval, registration, filing or other action necessary for the validity or enforceability of any Loan Document or the consummation of the transactions contemplated thereby, except (a) such as have been obtained or made and are in full force and effect, and (b) the Borrower may need to file a current report on Form 8‑K with the SEC disclosing this Amendment, (ii) will not violate any applicable law or regulation or the charter, by-laws or other organizational documents of the Borrower or any of its Subsidiaries or any order of any Governmental Authority, (iii) will not violate or result in a default under any indenture, agreement or other instrument binding upon the Borrower or any of its Subsidiaries or their Properties, or give rise to a right thereunder to require any payment to be made by the Borrower or such Subsidiary and (iv) will not result in the creation or imposition of any Lien on any Property of the Borrower or any of its Subsidiaries (other than the Liens created by the Loan Documents).
ARTICLE VI
Miscellaneous

Section 6.01      Credit Agreement in Full Force and Effect as Amended . Except as specifically amended hereby, the Credit Agreement and other Loan Documents shall remain in full force and effect and are hereby ratified and confirmed as so amended. Except as expressly set forth herein, this Amendment shall not be deemed to be a waiver, amendment or modification of any provisions of the Credit Agreement or any other Loan Document or any right, power or remedy of

8



the Administrative Agent or the Lenders, or constitute a waiver of any provision of the Credit Agreement or any other Loan Document, or any other document, instrument and/or agreement executed or delivered in connection therewith or of any Default or Event of Default under any of the foregoing, in each case whether arising before or after the date hereof or as a result of performance hereunder or thereunder. This Amendment also shall not preclude the future exercise of any right, remedy, power, or privilege available to the Administrative Agent and/or the Lenders whether under the Credit Agreement, the other Loan Documents, at law or otherwise. All references to the Credit Agreement shall be deemed to mean the Credit Agreement as modified hereby. The parties hereto agree to be bound by the terms and conditions of the Credit Agreement and Loan Documents as amended by this Amendment, as though such terms and conditions were set forth herein. Each reference in the Credit Agreement to “this Agreement,” “hereunder,” “hereof,” “herein” or words of similar import shall mean and be a reference to the Credit Agreement as amended by this Amendment, and each reference herein or in any other Loan Documents to the “Credit Agreement” shall mean and be a reference to the Credit Agreement as amended and modified by this Amendment.
Section 6.02      Governing Law . THIS AMENDMENT, AND THE RIGHTS AND OBLIGATIONS OF THE PARTIES HEREUNDER, SHALL BE CONSTRUED IN ACCORDANCE WITH AND BE GOVERNED BY THE LAWS OF THE STATE OF NEW YORK.
Section 6.03      Descriptive Headings, Etc . The descriptive headings of the sections of this Amendment are inserted for convenience only and shall not be deemed to affect the meaning or construction of any of the provisions hereof. The statements made and the terms defined in the recitals to this Amendment are hereby incorporated into this Amendment in their entirety.
Section 6.04      Entire Agreement . This Amendment and the documents referred to herein represent the entire understanding of the parties hereto regarding the subject matter hereof and supersede all prior and contemporaneous oral and written agreements of the parties hereto with respect to the subject matter hereof.
Section 6.05      Loan Document . This Amendment is a Loan Document executed under the Credit Agreement, and all provisions in the Credit Agreement pertaining to Loan Documents apply hereto.
Section 6.06      Counterparts . This Amendment may be executed in any number of counterparts and by different parties on separate counterparts, each of which shall constitute an original but all of which when taken together shall constitute but one agreement. Delivery of an executed counterpart of the signature page of this Amendment by facsimile or other electronic transmission shall be effective as delivery of a manually executed counterpart thereof.
Section 6.07      Successors . The execution and delivery of this Amendment by any Lender shall be binding upon each of its successors and assigns.

(Signature Pages Follow)

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IN WITNESS WHEREOF , the parties hereto have caused this Amendment to be duly executed by their respective authorized officers as of the date first written above.
NORTHERN OIL AND GAS, INC. , as the Borrower
By:     /s/ Thomas W. Stoelk
Name: Thomas W. Stoelk
Title: Chief Financial Officer




SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT



ROYAL BANK OF CANADA , as Administrative Agent


By: /s/ Rodica Dutka    
Name:    Rodica Dutka
Title:    Manager, Agency


ROYAL BANK OF CANADA , as a Lender


By:     /s/ Don J. McKinnerney    
Name:    Don J. McKinnerney
Title:    Authorized Signatory



SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT



SUNTRUST BANK , as a Lender


By:     /s/ Shannon Juhan    
Name:    Shannon Juhan
Title:    Director



SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT



BMO HARRIS FINANCING, INC. , as a Lender


By:     /s/ Melissa Guzmann    
Name:    Melissa Gezmann
Title:    Vice President



SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT



KEYBANK NATIONAL ASSOCIATION , as a Lender


By:     /s/ John Dravenstott    
Name:    John Dravenstott
Title:    Vice President




SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT



SANTANDER BANK, N.A. , as a Lender


By:     /s/ Aidan Lanigan    
Name:    Aidan Lanigan
Title:    Senior Vice President

By:     /s/ Payal Shah    
Name:    Payal Shah
Title:    Vice President



SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT



CAPITAL ONE, NATIONAL ASSOCIATION , as a Lender


By:     /s/ Robert James    
Name:    Robert James
Title:    Director



SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT



BOKF, NA dba BANK OF OKLAHOMA , as a Lender


By:     /s/ Parker Heikes    
Name:    Parker Heikes
Title:    Vice President



SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT



BRANCH BANKING & TRUST COMPANY , as a Lender


By:     /s/ Ryan K. Michael    
Name:    Ryan K. Michael
Title:    Senior Vice President



SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT



CADENCE BANK, N.A. , as a Lender


By:     /s/ Kyle Gruen    
Name:    Kyle Gruen
Title:    AVP



SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT



THE BANK OF NOVA SCOTIA , as a Lender


By:     /s/ Alan Dawson    
Name:    Alan Dawson
Title:    Director



SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT



ING CAPITAL LLC , as a Lender


By:     /s/ Josh Strong    
Name:    Josh Strong
Title:    Director

By:     /s/ Charles Hall    
Name:    Charles Hall
Title:    Managing Director



SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT



FIFTH THIRD BANK , as a Lender


By:     /s/ Thomas Kleiderer    
Name:    Thomas Kleiderer
Title:    Director


SIGNATURE PAGE
EIGHTH AMENDMENT TO CREDIT AGREEMENT

Exhibit 99.1
Northern Oil and Gas, Inc. Announces 2016 First Quarter Results and Borrowing Base Redetermination and Amendments under Revolving Credit Facility

WAYZATA, MINNESOTA — May 9, 2016 — Northern Oil and Gas, Inc. (NYSE MKT: NOG) today announced 2016 first quarter results, as well as a borrowing base redetermination and amendments under its revolving credit facility.

HIGHLIGHTS

Production averaged 13,552 barrels of oil equivalent (“Boe”) per day, for a total of 1,233,227 Boe
Oil and gas sales, including cash from settled derivatives, totaled $53.8 million
Northern added 41 gross (3.0 net) wells to production during the first quarter
Capital expenditures totaled $18.1 million during the first quarter, a reduction of 59% compared to the first quarter of 2015
Free cash flow was used to reduce Northern’s credit facility balance by $33 million during the first quarter, to $117 million
On May 6, 2016, the borrowing base under Northern’s revolving credit facility was set at $350 million, providing quarter-end liquidity of $237.4 million, composed of $4.4 million in cash and $233.0 million of revolving credit facility availability

Northern’s adjusted net income for the first quarter was $0.5 million, or $0.01 per diluted share. GAAP net loss for the quarter was $126.6 million, or a loss of $2.08 per diluted share, which was impacted by a combined $127.4 million of non-cash impairment charges, losses on the mark-to-market of derivative instruments and write-off of debt issuance costs. Adjusted EBITDA for the first quarter was $36.2 million. See “Non-GAAP Financial Measures” below for additional information on these measures.

MANAGEMENT COMMENT

“Our long standing focus on capital discipline allowed Northern to reduce spending, generate free cash flow and pay down an additional $33 million of debt during the quarter,” commented Northern’s Chief Executive Officer, Michael Reger. “With our borrowing base redetermination and the improvements to our covenant requirements, we are in a strong liquidity position to continue the execution of our business plan.”

LIQUIDITY

At March 31, 2016, Northern had $117 million in outstanding borrowings under its revolving credit facility, down from $150 million at December 31, 2015. On May 6 th the amended borrowing base was set at $350 million, providing quarter-end liquidity of $237.4 million, composed of $4.4 million in cash and $233.0 million of revolving credit facility availability.

In connection with the borrowing base redetermination, the credit agreement governing the revolving credit facility was amended to (i) reduce the minimum ratio of EBITDAX to interest expense that Northern will be required to maintain in future quarters, (ii) increase the interest rate on borrowings by 50 basis points and (iii) limit Northern’s ability to maintain excess cash liquidity without using it to reduce outstanding borrowings under the revolving credit facility.

HEDGING
Northern hedges portions of its expected production volumes to increase the predictability of its cash flow and to help maintain a strong financial position. The following table summarizes Northern’s open crude oil swap derivative contracts scheduled to settle after March 31, 2016.

Contract Period
 
Volume (Bbls)
 
Weighted Average Price (per Bbl)
2016:
 
 
 
 
Q2
 
450,000
 

$90.00

Q3
 
450,000
 

$65.00

Q4
 
450,000
 

$65.00





CAPITAL EXPENDITURES & DRILLING ACTIVITY

 
 
First Quarter
2016
Capital Expenditures Incurred:
 
 
Drilling, Completion & Capitalized Workover Expense
 
$15.4 million
Acreage
 
$1.6 million
Other
 
$1.1 million
 
 
 
Net Wells Added to Production
 
3.0
Net Producing Wells (Period-End)
 
207.3
 
 
 
Net Wells in Process (Period-End)
 
7.3
 
 
 
Weighted Average AFE for In-Process Wells (Period End)
 
$7.8 million

For the first quarter, the weighted average authorization for expenditure (or AFE) cost for wells that Northern elected to participate in (consented) was $7.1 million.

GUIDANCE

Despite first quarter curtailments that reduced production by approximately 1,600 Boe per day during the quarter, Northern continues to expect 2016 total production to be down approximately 15% compared to 2015 production levels, with full year capital expenditures expected to total between $60 and $70 million. Management’s current expectations for certain 2016 operating metrics are as follows:

 
 
2016
Operating Expenses:
 
 
Production Expenses (per Boe)
 
$9.00 - $9.50
Production Taxes (% of Oil & Gas Sales)
 
10%
General and Admin. Expense (per Boe)
 
$3.75 - $4.25
 
 
 
Average Differential to NYMEX WTI
 
($8.00) to ($10.00)

ACREAGE

As of March 31, 2016, Northern controlled 164,894 net acres targeting the Williston Basin Bakken and Three Forks formations. During the first quarter of 2016, Northern acquired leasehold interests covering an aggregate of approximately 764 net acres, for an average cost of $1,214 per net acre. As of March 31, 2015, approximately 81% of Northern’s North Dakota acreage position, and approximately 74% of Northern’s total acreage position, was developed, held by production or held by operations.

FIRST QUARTER 2016 RESULTS

The following table sets forth selected operating and financial data for the periods indicated.




 
Three Months Ended
March 31,
 
2016
 
2015
 
% Change
Net Production:
 
 
 
 
 
Oil (Bbl)
1,107,989

 
1,328,510

 
(17)
Natural Gas and NGLs (Mcf)
751,424

 
1,202,455

 
(38)
Total (Boe)
1,233,227

 
1,528,919

 
(19)
 
 
 
 
 
 
Average Daily Production:
 
 
 
 
 
Oil (Bbl)
12,176

 
14,761

 
(18)
Natural Gas and NGL (Mcf)
8,257

 
13,361

 
(38)
Total (Boe)
13,552

 
16,988

 
(20)
 
 
 
 
 
 
Average Sales Prices:
 
 
 
 
 
Oil (per Bbl)
$
24.61

 
$
36.12

 
(32)
Effect of Gain on Settled Derivatives on Average Price (per Bbl)
22.97

 
30.10

 
(24)
Oil Net of Settled Derivatives (per Bbl)
47.58

 
66.22

 
(28)
Natural Gas and NGLs (per Mcf)
1.47

 
2.05

 
(28)
Realized Price on a Boe Basis Including all Realized Derivative Settlements
43.64

 
59.16

 
(26)
 
 
 
 
 
 
Costs and Expenses (per Boe):
 
 
 
 
 
Production Expenses
$
9.70

 
$
9.29

 
              4
Production Taxes
2.24

 
3.54

 
(37)
General and Administrative Expense
3.52

 
2.85

 
             24
Depletion, Depreciation, Amortization and Accretion
14.47

 
29.57

 
(51)
 
 
 
 
 
 
Net Producing Wells at Period End
207.3

 
192.3

 
               8

Oil and Natural Gas Sales

In the first quarter of 2016, oil, natural gas and NGL sales decreased 44% as compared to the first quarter of 2015, driven by a 30% decrease in realized prices, excluding the effect of settled derivatives, and a 19% decrease in production. The lower average realized price in the first quarter of 2016 as compared to the same period in 2015 was principally driven by lower average NYMEX oil and gas prices, which were partially offset by a lower oil price differential. Oil price differential during the first quarter of 2016 was $9.02 per barrel, as compared to $12.45 per barrel in the first quarter of 2015.

Beginning in 2016, certain of our operators began curtailing production due to their desire to produce the wells at higher prices than currently exist. We estimate the impact from this curtailed production reduced production in the first quarter of 2016 by approximately 1,600 barrels of oil equivalent per day.

Derivative Instruments (Hedges)

Northern enters into derivative instruments to manage the price risk attributable to future oil production. Gain (loss) on derivative instruments, net is comprised of (i) cash gains and losses recognized on settled derivatives during the period, and (ii) non-cash mark-to-market gains and losses incurred on derivative instruments outstanding at period-end.




 
Three Months Ended
March 31,
 
2016
 
2015
 
(in millions)
Derivative Instruments (Hedges):
 
 
 
Cash Derivative Settlements
$
25.5

 
$
40.0

Non-Cash Mark-to-Market of Derivative Instruments
(22.0)

 
(14.3)

Gain on Derivative Instruments, Net
$
3.5

 
$
25.7


Northern’s average realized price (including all cash derivative settlements) received during the first quarter of 2016 was $43.64 per Boe compared to $59.16 per Boe in the first quarter of 2015. The gain on settled derivatives increased Northern’s average realized price per Boe by $20.64 in the first quarter of 2016 and by $26.16 in the first quarter of 2015.

As a result of forward oil price changes, Northern recognized a non-cash mark-to-market derivative loss of $22.0 million in the first quarter of 2016, compared to a loss of $14.3 million in the first quarter of 2015.

Production Expenses

Production expenses decreased from $14.2 million in the first quarter of 2015 to $12.0 million in the first quarter of 2016. On a per unit basis, production expenses increased 4% from the first quarter of 2015 to $9.70 per Boe in the first quarter of 2016 due to lower production levels.

Production Taxes

Northern pays production taxes based on realized crude oil and natural gas sales. These costs were $2.8 million in the first quarter of 2016 compared to $5.4 million in the first quarter of 2015. As a percentage of oil and natural gas sales, production taxes decreased to 9.8% in the first quarter of 2016 from 10.7% in the first quarter of 2015.
General and Administrative Expense

General and administrative expense was $4.3 million for the first quarter of 2016 compared to $4.4 million for the first quarter of 2015. Lower compensation expenses in the first quarter of 2016 were offset by higher legal and professional expenses.

Depletion, Depreciation, Amortization and Accretion

Depletion, depreciation, amortization and accretion (“DD&A”) was $17.8 million in the first quarter of 2016 compared to $45.2 million in the first quarter of 2015. Depletion expense, the largest component of DD&A, decreased by $27.3 million in the first quarter of 2016 as compared to the first quarter of 2015. On a per Boe basis, depletion expense was $14.35 per Boe in the first quarter of 2016 compared to $29.45 per Boe in the first quarter of 2015. The year-over-year decrease was due to the impairment of oil and gas properties, which lowered the depletable base.

Impairment of Oil and Natural Gas Properties

As a result of current low commodity prices and their effect on the proved reserve values of properties, Northern recorded a non-cash ceiling test impairment of $104.3 million in the first quarter of 2016 and $360.4 million in the first quarter of 2015. The impairment charge affected reported net income but did not reduce cash flow.

Interest Expense & Write-off of Debt Issuance Costs

Interest expense, net of capitalized interest, was $16.1 million in the first quarter of 2016 compared to $11.7 million in the first quarter of 2015. The increase in interest expense for the first quarter of 2016 as compared to the first quarter of 2015 was primarily due to a higher average cost of borrowing between periods. In May 2015, Northern closed a $200 million Senior Notes offering, and these notes bear a higher interest rate as compared to borrowings under the revolving credit facility.

During the three months ended March 31, 2016, $1.1 million of debt issuance costs were written-off as a result of the reduction in the borrowing base.




Income Tax Provision

Northern recognized no income tax benefit during the first quarter of 2016 due to a valuation allowance placed on its net deferred tax asset. This compares to an income tax benefit of $135.5 million or 37.1% in the first quarter of 2015.

Net Income

Northern recorded a net loss of $126.6 million, or a loss of $2.08 per diluted share, for the first quarter of 2016, compared to a net loss of $229.7 million, or a loss of $3.79 per diluted share, for the first quarter of 2015. The net loss in the first quarter of 2016 was impacted by the non-cash impairment of oil and natural gas properties, the valuation allowance placed on the net deferred tax asset, write-off of debt issuance costs and a non-cash loss on the mark-to-market of derivative instruments.

Non-GAAP Financial Measures

Adjusted Net Income for the first quarter of 2016 was $0.5 million (representing $0.01 per diluted share), compared to $6.0 million (representing approximately $0.10 per diluted share) for the first quarter of 2015. Northern defines Adjusted Net Income as net income excluding (i) (gain) loss on the mark-to-market of derivative instruments, (ii) write-off of debt issuance costs and, (iii) impairment of oil and natural gas properties, net of tax.

Adjusted EBITDA for the first quarter of 2016 was $36.2 million, compared to Adjusted EBITDA of $67.5 million for the first quarter of 2015. The decrease in Adjusted EBITDA is primarily due to lower realized commodity prices and lower production in the first quarter of 2016 compared to the first quarter of 2015. Northern defines Adjusted EBITDA as net income before (i) interest expense, (ii) income taxes, (iii) depreciation, depletion, amortization, and accretion, (iv) (gain) loss on the mark-to-market of derivative instruments, (v) non-cash share based compensation expense, (vi) write-off of debt issuance costs and (vii) impairment of oil and natural gas properties.

Adjusted Net Income and Adjusted EBITDA are non-GAAP measures. A reconciliation of these measures to the most directly comparable GAAP measure is included in the accompanying financial tables found later in this release. Management believes the use of these non-GAAP financial measures provides useful information to investors to gain an overall understanding of current financial performance. Specifically, management believes the non-GAAP results included herein provide useful information to both management and investors by excluding certain expenses and unrealized derivatives gains and losses that management believes are not indicative of Northern’s core operating results. In addition, these non-GAAP financial measures are used by management for budgeting and forecasting as well as subsequently measuring Northern’s performance, and management believes it is providing investors with financial measures that most closely align to its internal measurement processes.

FIRST QUARTER 2016 EARNINGS RELEASE CONFERENCE CALL

In conjunction with Northern’s release of its financial and operating results, investors, analysts and other interested parties are invited to listen to a conference call with management on Tuesday May 10, 2016 at 11:00 a.m. Central Time.

Those wishing to listen to the conference call may do so via the company’s website, www.northernoil.com , or by phone as follows:

Dial-In Number : (855) 638-5677 (US/Canada) and (262) 912-4762 (International)
Conference ID : 1179256 - Northern Oil and Gas, Inc. First Quarter 2016 Earnings Call
Replay Dial-In Number : (855) 859-2056 (US/Canada) and (404) 537-3406 (International)
Replay Access Code : 1179256 - Replay will be available through May 17, 2016

UPCOMING CONFERENCE SCHEDULE

2016 Global Energy and Power Executive Conference
June 6 – 7, 2016, New York, NY
EnerCom’s The Oil & Gas Conference 21
August 14 – 18, 2016, Denver, CO




ABOUT NORTHERN OIL AND GAS

Northern Oil and Gas, Inc. is an exploration and production company with a core area of focus in the Williston Basin Bakken and Three Forks play in North Dakota and Montana.

More information about Northern Oil and Gas, Inc. can be found at www.NorthernOil.com .

SAFE HARBOR

This press release contains forward-looking statements regarding future events and future results that are subject to the safe harbors created under the Securities Act of 1933 (the “Securities Act”) and the Securities Exchange Act of 1934 (the “Exchange Act”). All statements other than statements of historical facts included in this release regarding Northern’s financial position, business strategy, plans and objectives of management for future operations, industry conditions, and indebtedness covenant compliance are forward-looking statements. When used in this release, forward-looking statements are generally accompanied by terms or phrases such as “estimate,” “project,” “predict,” “believe,” “expect,” “anticipate,” “target,” “plan,” “intend,” “seek,” “goal,” “will,” “should,” “may” or other words and similar expressions that convey the uncertainty of future events or outcomes. Items contemplating or making assumptions about actual or potential future sales, market size, collaborations, and trends or operating results also constitute such forward-looking statements.

Forward-looking statements involve inherent risks and uncertainties, and important factors (many of which are beyond Northern’s control) that could cause actual results to differ materially from those set forth in the forward-looking statements, including the following: changes in crude oil and natural gas prices, the pace of drilling and completions activity on Northern’s properties, Northern’s ability to acquire additional development opportunities, changes in Northern’s reserves estimates or the value thereof, general economic or industry conditions, nationally and/or in the communities in which Northern conducts business, changes in the interest rate environment, legislation or regulatory requirements, conditions of the securities markets, Northern’s ability to raise capital, changes in accounting principles, policies or guidelines, financial or political instability, acts of war or terrorism, and other economic, competitive, governmental, regulatory and technical factors affecting Northern’s operations, products, services and prices.

Northern has based these forward-looking statements on its current expectations and assumptions about future events. While management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond Northern’s control.

CONTACT:

Brandon Elliott, CFA
Executive Vice President
Corporate Development and Strategy
952-476-9800
belliott@northernoil.com

SOURCE Northern Oil and Gas, Inc.






NORTHERN OIL AND GAS, INC.
CONDENSED STATEMENTS OF OPERATIONS
FOR THE THREE MONTHS ENDED MARCH 31, 2016 AND 2015
(UNAUDITED)

 
Three Months Ended
March 31,
 
2016
 
2015
REVENUES
 
 
 
Oil and Gas Sales
$
28,367,341

 
$
50,454,148

Gain on Derivative Instruments, Net
3,463,883

 
25,663,283

Other Revenue
5,012

 
7,207

Total Revenues
31,836,236

 
76,124,638

 
 
 
 
OPERATING EXPENSES
 

 
 

Production Expenses
11,959,260

 
14,199,090

Production Taxes
2,766,899

 
5,413,108

General and Administrative Expense
4,337,402

 
4,352,806

Depletion, Depreciation, Amortization and Accretion
17,846,089

 
45,213,039

Impairment of Oil and Natural Gas Properties
104,311,122

 
360,428,962

Total Expenses
141,220,772

 
429,607,005

 
 
 
 
LOSS FROM OPERATIONS
(109,384,536
)
 
(353,482,367
)
 
 
 
 
OTHER INCOME (EXPENSE)
 

 
 

Interest Expense, Net of Capitalization
(16,098,682
)
 
(11,736,547
)
Write-off of Debt Issuance Costs
(1,089,507
)
 

Other Income (Expense)
6,971

 
342

Total Other Income (Expense)
(17,181,218
)
 
(11,736,205
)
 
 
 
 
LOSS BEFORE INCOME TAXES
(126,565,754
)
 
(365,218,572
)
 
 
 
 
INCOME TAX PROVISION (BENEFIT)

 
(135,480,000
)
 
 
 
 
NET LOSS
$
(126,565,754
)
 
$
(229,738,572
)
 
 
 
 
Net Loss Per Common Share – Basic
$
(2.08
)
 
$
(3.79
)
Net Loss Per Common Share – Diluted
$
(2.08
)
 
$
(3.79
)
Weighted Average Shares Outstanding – Basic
60,964,029

 
60,556,180

Weighted Average Shares Outstanding – Diluted
60,964,029

 
60,556,180






NORTHERN OIL AND GAS, INC.
CONDENSED BALANCE SHEETS
MARCH 31, 2016 AND DECEMBER 31, 2015

 
March 31, 2016
(unaudited)
 
December 31, 2015
ASSETS
 
 
 
Current Assets:
 
 
 
Cash and Cash Equivalents
$
4,388,142

 
$
3,390,389

Trade Receivables, Net
29,704,685

 
51,445,026

Advances to Operators
1,650,977

 
1,689,879

Prepaid and Other Expenses
765,838

 
892,867

Derivative Instruments
42,628,541

 
64,611,558

Total Current Assets
79,138,183

 
122,029,719

 
 
 
 
Property and Equipment
 

 
 

Oil and Natural Gas Properties, Full Cost Method of Accounting
 

 
 

Proved
2,360,273,521

 
2,336,757,089

Unproved
4,590,118

 
10,007,529

Other Property and Equipment
1,812,833

 
1,837,469

Total Property and Equipment
2,366,676,472

 
2,348,602,087

Less – Accumulated Depreciation, Depletion and Impairment
(1,881,317,642
)
 
(1,759,281,704
)
Total Property and Equipment, Net
485,358,830

 
589,320,383

 
 
 
 
Deferred Income Taxes (Note 9)

 

Other Noncurrent Assets, Net
8,691,724

 
10,080,846

 
 
 
 
Total Assets
$
573,188,737

 
$
721,430,948

 
 
 
 
LIABILITIES AND STOCKHOLDERS’ EQUITY (DEFICIT)
Current Liabilities:
 

 
 

Accounts Payable
$
62,860,879

 
$
65,319,170

Accrued Expenses
5,080,643

 
7,893,975

Accrued Interest
18,674,412

 
4,713,232

Asset Retirement Obligations
194,796

 
188,770

Total Current Liabilities
86,810,730

 
78,115,147

 
 
 
 
Long-term Debt
803,121,312

 
835,290,329

Asset Retirement Obligations
5,761,738

 
5,627,586

 
 
 
 
Total Liabilities
$
895,693,780

 
$
919,033,062

 
 
 
 
Commitments and Contingencies (Note 8)
 
 
 
 
 
 
 
STOCKHOLDERS’ EQUITY (DEFICIT)
 

 
 

Preferred Stock, Par Value $.001; 5,000,000 Authorized, No Shares Outstanding

 

Common Stock, Par Value $.001; 95,000,000 Authorized (3/31/2016 – 63,732,441
       Shares Outstanding and 12/31/2015 – 63,120,384 Shares Outstanding)
63,732

 
63,120

Additional Paid-In Capital
441,883,231

 
440,221,018

Retained Earnings (Deficit)
(764,452,006
)
 
(637,886,252
)
Total Stockholders’ Equity (Deficit)
(322,505,043
)
 
(197,602,114
)
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY (DEFICIT)
$
573,188,737

 
$
721,430,948






Reconciliation of Adjusted Net Income

 
Three Months Ended
March 31,
 
2016
 
2015
Net Loss
$
(126,565,754
)
 
$
(229,738,572
)
Add:
 

 
 

Impact of Selected Items:
 

 
 

Loss on the Mark-to-Market of Derivative Instruments
21,983,017

 
14,331,367

Write-off of Debt Issuance Costs
1,089,507

 

Impairment of Oil and Natural Gas Properties
104,311,122

 
360,428,962

Selected Items, Before Income Taxes (Benefit)
127,383,646

 
374,760,329

Income Tax of Selected Items (1)
(272,729
)
 
(139,036,082
)
Selected Items, Net of Income Taxes (Benefit)
127,110,917

 
235,724,247

 
 
 
 
Adjusted Net Income
$
545,163

 
$
5,985,675

 
 
 
 
Weighted Average Shares Outstanding – Basic
60,964,029

 
60,556,180

Weighted Average Shares Outstanding – Diluted
61,543,796

 
60,633,200

 
 
 
 
Net Loss Per Common Share – Basic
$
(2.08
)
 
(3.79
)
Add:
 

 
 

Impact of Selected Items, Net of Income Taxes (Benefit)
2.09

 
3.89

Adjusted Net Income Per Common Share – Basic
$
0.01

 
$
0.10

 
 
 
 
Net Loss Per Common Share – Diluted
$
(2.06
)
 
(3.79
)
Add:
 

 
 

Impact of Selected Items, Net of Income Taxes (Benefit)
2.07

 
3.89

Adjusted Net Income Per Common Share – Diluted
$
0.01

 
$
0.10

______________

(1)
For the 2016 column, this represents a tax impact using an estimated tax rate of 35.9% and 37.1% for the three months ended March 31, 2016 and 2015, respectively.  For 2016, this column includes a $45.5 million adjustment for a change in valuation allowance for the three months ended March 31, 2016.




Reconciliation of Adjusted EBITDA

 
Thee Months Ended
March 31,
 
2016
 
2015
Net Loss
$
(126,565,754
)
 
$
(229,738,572
)
Add:
 

 
 

Interest Expense
16,098,682

 
11,736,547

Income Tax Provision (Benefit)

 
(135,480,000
)
Depreciation, Depletion, Amortization and Accretion
17,846,089

 
45,213,039

Impairment of Oil and Natural Gas Properties
104,311,122

 
360,428,962

Non-Cash Share Based Compensation
1,391,793

 
1,030,317

Write-off of Debt Issuance Costs
1,089,507

 

Loss on the Mark-to-Market of Derivative Instruments
21,983,017

 
14,331,367

Adjusted EBITDA
$
36,154,456

 
$
67,521,660