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): March 13, 2014 (March 12, 2014)


GASTAR EXPLORATION INC.
(Exact Name of Registrant as Specified in its Charter)

    

DELAWARE
 
001-35211
 
38-3531640
(State or other jurisdiction
 
(Commission File Number)
 
(IRS Employer
of incorporation)
 
 
 
Identification No.)


(713) 739-1800
(Registrant's telephone number, including area code)


Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):
 
 
 
[ ]
Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
[ ]
Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
[ ]
Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
[ ]
Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))


 







SECTION 1 - REGISTRANT'S BUSINESS AND OPERATIONS

Item 1.01. Entry into a Material Definitive Agreement.

Agreement, Waiver and Amendment No. 3 to Second Amended and Restated Credit Agreement
On March 12, 2014, Gastar Exploration Inc. (NYSE MKT: GST) (formerly known as “Gastar Exploration USA, Inc.”) (the “Company”), together with the parties thereto, entered into the Agreement, Waiver and Amendment No. 3 (“Amendment No. 3”) to the Second Amended and Restated Credit Agreement, dated as of June 7, 2013, among the Company, as Borrower, Wells Fargo Bank, National Association, as Administrative Agent, Collateral Agent, Swing Line Lender and issuing Lender, and the Lenders named therein (the “Revolving Credit Facility”). Amendment No. 3 amended the Revolving Credit Facility to, among other things, (i) permit the Company to exclude current and future subsidiaries that are deemed to be immaterial from becoming guarantors of the Revolving Credit Facility, provided such non-guarantor subsidiaries comply with certain restrictions, (ii) exclude the non-guarantor subsidiaries from the provisions of the negative covenants of the Revolving Credit Facility with respect to mergers and acquisitions, restricted payments, and investments and (iii) exclude the non-guarantor subsidiaries from being included in the calculation of the borrowing base under the Revolving Credit Facility.
A copy of Amendment No. 3 is attached as Exhibit 10.1 to this Current Report on Form 8-K and incorporated herein by reference and is hereby filed. The description of Amendment No. 3 in this Current Report is a summary and is qualified in its entirety by reference to the complete text of such agreement.

SECTION 2 - FINANCIAL INFORMATION

Item 2.02 Results of Operations and Financial Condition.

On March 13, 2014, the Company issued a press release announcing the Company’s financial results for the three and twelve months ended December 31, 2013. A copy of the Company’s press release, dated March 13, 2014, is furnished herewith as Exhibit 99.1 and is incorporated herein by reference.

In accordance with General Instruction B.2 of Form 8-K, the information presented herein under Item 2.02, including the press release attached as Exhibit 99.1 and incorporated by reference into this Item 2.02, shall not be deemed to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), or otherwise subject to the liabilities of that section, nor shall such information be deemed incorporated by reference into any filing under the Securities Act of 1933, as amended, or the Exchange Act, unless specifically identified in such filing as being incorporated therein by reference.

SECTION 9 – FINANCIAL STATEMENTS AND EXHIBITS

Item 9.01 Financial Statements and Exhibits

(d) Exhibits

The following is a list of exhibits filed or furnished as part of this Form 8-K:

Exhibit No.          Description of Document    

10.1
Agreement, Waiver and Amendment No. 3 to Second Amended and Restated Credit Agreement, dated as of March 12, 2014, among Gastar Exploration Inc. as borrower, Wells Fargo Bank, National Association, as Administrative Agent, Collateral Agent, Swing Line Lender and issuing Lender, and the Lenders named therein.
99.1
Press release dated March 13, 2014 announcing the Company's financial results for the three and twelve months ended December 31, 2013.

    



SIGNATURES

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



Date: March 13, 2014
GASTAR EXPLORATION INC.
 
 
 
 
 
By:
/s/ J. Russell Porter
 
 
J. Russell Porter
 
 
 
President and Chief Executive Officer


    



EXHIBIT INDEX

Exhibit No.          Description of Document    

10.1
Agreement, Waiver and Amendment No. 3 to Second Amended and Restated Credit Agreement, dated as of March 12, 2014, among Gastar Exploration Inc. as borrower, Wells Fargo Bank, National Association, as Administrative Agent, Collateral Agent, Swing Line Lender and issuing Lender, and the Lenders named therein.
99.1
Press release dated March 13, 2014 announcing the Company's financial results for the three and twelve months ended December 31, 2013.





    
Exhibit 10.1

AGREEMENT, WAIVER AND AMENDMENT NO. 3 TO
SECOND AMENDED AND RESTATED CREDIT AGREEMENT

This Agreement, Waiver and Amendment No. 3 to Second Amended and Restated Credit Agreement (" Agreement ") dated as of March 12, 2014 (" Effective Date "), is among Gastar Exploration Inc., a Delaware corporation and formerly known as “Gastar Exploration USA, Inc.” (" Borrower "), the Guarantors (as defined in the Credit Agreement referenced below), the Lenders (as defined below), and Wells Fargo Bank, National Association, as administrative agent for such Lenders (in such capacity, the " Administrative Agent "), as collateral agent (in such capacity, the " Collateral Agent "), as swing line lender (in such capacity, " Swing Line Lender "), and as issuing lender (in such capacity, the " Issuing Lender ").

RECITALS

A. The Borrower is party to that certain Second Amended and Restated Credit Agreement dated as of June 7, 2013, among the Borrower, the lenders thereto from time to time (the " Lenders "), the Administrative Agent, the Collateral Agent, the Swing Line Lender, and the Issuing Lender, as heretofore amended (as so amended, the " Credit Agreement ").

B. The Borrower has requested that Administrative Agent and the Lenders, subject to the terms and conditions set forth herein, (i) amend the Credit Agreement as provided herein and (ii) provide a waiver of the Event of Default arising as a result of the Borrower changing its name to “Gastar Exploration Inc.” without the necessary notice and consent required under Section 6.11 of the Credit Agreement (the “ Existing Default ”).

THEREFORE, the Borrower, the Guarantors, the Lenders, the Issuing Lender, the Swing Line Lender, the Collateral Agent, and the Administrative Agent hereby agree as follows:
Section 1. Defined Terms; Interpretation . As used in this Agreement, each of the terms defined in the opening paragraph and the Recitals above shall have the meanings assigned to such terms therein. Each term defined in the Credit Agreement and used herein without definition shall have the meaning assigned to such term in the Credit Agreement, unless expressly provided to the contrary. The words "hereby", "herein", "hereinafter", "hereof", "hereto" and "hereunder" when used in this Agreement shall refer to this Agreement as a whole and not to any particular Article, Section, subsection or provision of this Agreement. Article, Section, subsection and Exhibit references herein are to such Articles, Sections, subsections and Exhibits of this Agreement unless otherwise specified. All titles or headings to Articles, Sections, subsections or other divisions of this Agreement or the exhibits hereto, if any, are only for the convenience of the parties and shall not be construed to have any effect or meaning with respect to the other content of such Articles, Sections, subsections, other divisions or exhibits, such other content being controlling as the agreement among the parties hereto. Whenever the context requires, reference herein made to the single number shall be understood to include the plural; and likewise, the plural shall be understood to include the singular. Words denoting sex shall be construed to include the masculine, feminine and neuter, when such construction is appropriate; and specific enumeration shall not exclude the




general but shall be construed as cumulative. Definitions of terms defined in the singular or plural shall be equally applicable to the plural or singular, as the case may be, unless otherwise indicated.
Section 1.      Waiver . The Borrower hereby acknowledges the existence of the Existing Default. Subject to the terms and conditions of this Agreement, the Lenders hereby waive the Existing Default. The waiver by the Lenders described in this Section 2 is limited to the Existing Default and shall not be construed to be a consent to, or a permanent waiver of, noncompliance with Section 6.11 of the Credit Agreement, or any other terms, provisions, covenants, warranties or agreements contained in the Credit Agreement or in any of the other Loan Documents. The Lenders expressly reserve the right to exercise any rights and remedies available to them in connection with any present or future defaults with respect to the Credit Agreement or any other provision of any Loan Document other than the Existing Default. The description herein of the Existing Default is based upon the information provided to the Lenders on or prior to the date hereof and shall not be deemed to exclude the existence of any other Defaults or Events of Default. The failure of the Lenders to give notice to any Loan Party of any such other Defaults or Events of Default is not intended to be nor shall be a waiver thereof. Each Loan Party hereby agrees and acknowledges that the Lenders require and will require strict performance by the Loan Parties of all of their respective obligations, agreements and covenants contained in the Credit Agreement and the other Loan Documents, and no inaction or action by the Administrative Agent, the Collateral Agent, the Issuing Lender, the Swing Line Lender, or any Lender regarding any Default or Event of Default (including but not limited to the Existing Default) under any of the Loan Documents is intended to be or shall be a waiver thereof other than the waiver of the Existing Default expressly provided for in this Section 2 . Other than the waiver of the Existing Default expressly provided for in this Section 2 , each Loan Party hereby also agrees and acknowledges that no course of dealing and no delay in exercising any right, power, or remedy conferred to any Lender in the Credit Agreement or in any other Loan Document or now or hereafter existing at law, in equity, by statute, or otherwise shall operate as a waiver of or otherwise prejudice any such right, power, or remedy (collectively, the " Lender Rights "). For the avoidance of doubt, each Loan Party also agrees and acknowledges that neither the waiver provided in this Agreement nor any other waiver provided by the Lenders prior to the date hereof shall operate as a waiver of or otherwise prejudice any of the Lender Rights other than the waiver of the Existing Default expressly provided for in this Section 2 .
Section 2.      Amendments to Credit Agreement.
(a)      The cover page and page 1 of the Credit Agreement are hereby amended by placing each reference to “Gastar Exploration USA, Inc.” with a reference to “ Gastar Exploration Inc.”
(b)      Section 1.01 of the Credit Agreement (Certain Defined Terms) is hereby amended by deleting the definition for “Borrowing Base” and replacing it with the following:
Borrowing Base ” means at any particular time, the Dollar amount determined in accordance with Section 2.02 on account of Proven Reserves attributable to Oil and Gas Properties of the Loan Parties and their Subsidiaries (other than Non-Guarantor Subsidiaries).

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(c)      Section 1.01 of the Credit Agreement (Certain Defined Terms) is hereby amended by adding the following terms to appear in the appropriate alphabetical order:
Immaterial Subsidiary ” means any Subsidiary, when taken together with all other Subsidiaries that are not Guarantors at the time of determination, at such time has either assets or quarterly revenues of less than 2.00% of the consolidated assets or quarterly revenues of the Borrower and its consolidated Subsidiaries, in each case, based upon the most recent financial statements available to the Borrower; provided that, in any event, if any Subsidiary (i) provides a guarantee, collateral or any other credit support for any Debt of the Borrower or any other Subsidiary or (ii) incurs any Debt (other than purchase money indebtedness or capital leases incurred in the ordinary course of business and permitted under Section 6.02(b) and limited in amount as provided in Section 6.01(b)), such Subsidiary shall not be an Immaterial Subsidiary regardless of the value of its assets or amount of quarterly revenues.

Net Investment Amount ” means, as of any date of determination, the amount equal to (a) the aggregate amount of Investments made by Loan Parties to Non-Guarantor Subsidiaries since the Effective Date, including the initial Investments made to create such Subsidiaries, minus (b) the aggregate amount of Restricted Payments made by Non-Guarantor Subsidiaries to the Loan Parties since the Effective Date (it being agreed that the amount of such Restricted Payment that constitute Property shall be deemed to be the purchase price for such Property that was acquired with the proceeds of Investments made by the Loan Parties to the Non-Guarantor Subsidiaries).

Non-Guarantor Subsidiary ” means any Immaterial Subsidiary so long as such Subsidiary is not a Guarantor.

(d)      Section 5.06 of the Credit Agreement (Reporting Requirements) is hereby amended by replacing clause (a), clause (b) and clause (l) in their entirety with the corresponding clause (a), clause (b) and clause (l) set forth below:
(a)     Annual Financials . As soon as available and in any event not later than 90 days after the end of each fiscal year of the Borrower and its consolidated Subsidiaries, commencing with fiscal year ending December 31, 2013, (i) a copy of the annual audit report for such year for the Borrower and its consolidated Subsidiaries, including therein the Borrower’s and its consolidated Subsidiaries’ balance sheets as of the end of such fiscal year and the Borrower’s and its consolidated Subsidiaries’ statements of income, cash flows, and retained earnings, in each case certified by an independent certified public accountants reasonably acceptable to the Administrative Agent and including any management letters delivered by such accountants to the Borrower or any Subsidiary in connection with such audit, (ii) any management letters delivered by such accountants to the Borrower or any Subsidiary, (iii) a Compliance Certificate executed by a Responsible Officer of the Borrower, and (iv) an officer’s certificate setting forth the Borrower’s

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and its consolidated Subsidiaries’ assets or quarterly revenues and the calculations reflecting whether a Subsidiary is an Immaterial Subsidiary based on the financial statements for such fiscal year end, with such details and supporting document that the Administrative Agent may reasonably request;

(b)     Quarterly Financials . As soon as available and in any event not later than 60 days after the end of each fiscal quarter of each fiscal year of each Loan Party and its consolidated Subsidiaries, (i) commencing with the fiscal quarter ending June 30, 2013, the unaudited balance sheet and the statements of income, cash flows, and retained earnings of each such Person for the period commencing at the end of the previous year and ending with the end of such fiscal quarter, all in reasonable detail and duly certified with respect to such consolidated statements (subject to yearend audit adjustments) by a Responsible Officer of the Borrower as having been prepared in accordance with GAAP, (ii) a Compliance Certificate executed by the Responsible Officer of the Borrower, and (iii) an officer’s certificate setting forth the Borrower’s and its consolidated Subsidiaries’ assets or quarterly revenues and the calculations reflecting whether a Subsidiary is an Immaterial Subsidiary based on the financial statements for such fiscal year end, with such details and supporting document that the Administrative Agent may reasonably request;

(l)     Material Changes . Prompt written notice of any condition or event of which any Loan Party or Subsidiary has knowledge, which condition or event (i) has resulted or could reasonably be expected to result in a Material Adverse Change, (ii) has resulted in a breach of or noncompliance with any material term, condition, or covenant of any material contract to which any Loan Party or Subsidiary is a party or by which they or their Properties are bound, or (iii) has resulted or could reasonably be expected to result in a Subsidiary ceasing to be an Immaterial Subsidiary;

(e)      Section 6.04 of the Credit Agreement (Merger or Consolidation; Asset Sales) is hereby amended by replacing clause (b)(iii) therein in its entirety with the following:
(iii)    (A) the Disposition of Property between or among a Guarantor (other than the Parent) and the Borrower or between or among Guarantors (other than the Parent), (B) the transfer of Property in the form of a Restricted Payment by an Immaterial Subsidiary to the Borrower or a Guarantor, and (C) the sale of Property by an Immaterial Subsidiary to the Borrower or a Guarantor so long as the terms thereof are satisfactory to the Administrative Agent;

(f)      Section 6.05 of the Credit Agreement (Restricted Payments) is hereby amended by replacing clause (b) and clause (c) in their entirety with the corresponding clause (b) and clause (c) set forth below:
(b)     any Guarantor may make Restricted Payments to any other Guarantor and to the Borrower; and


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(c)    a Non-Guarantor Subsidiary may make Restricted Payments to any Guarantor and to the Borrower.

(g)      Section 6.06 of the Credit Agreement (Investments) is hereby amended by replacing clause (c) therein in its entirety with the following:
(c)     (i) creation of any Immaterial Subsidiary in compliance with Section 6.15 and other Investments made by any Loan Party to any Non-Guarantor Subsidiary solely for the purpose of such Non-Guarantor Subsidiary purchasing Oil and Gas Properties; provided that, the aggregate Net Investment Amount shall not, at any time, exceed 2.00% of the consolidated assets or quarterly revenues of the Borrower and its consolidated Subsidiaries, in each case, based upon the most recent financial statements available to the Borrower, and (ii) creation of any Subsidiary that becomes a Guarantor in compliance with Section 6.15 and other Investments made by any Loan Party to any other Loan Party;

(h)      Section 6.15 of the Credit Agreement (Additional Subsidiaries) is hereby replaced in its entirety with the following:
Section 6.15 Additional Subsidiaries . No Loan Party shall, nor shall any Loan Party permit any of its Subsidiaries to, create or acquire any additional Subsidiaries without (a) providing the Administrative Agent with notice of such creation or acquisition within ten (10) days after such creation or acquisition (or such later time period acceptable to the Administrative Agent in its sole discretion), (b) such new Subsidiary that is not an Immaterial Subsidiary executing and delivering to the Collateral Agent, at either Agent’s request and within the time period requested by such Agent, a Guaranty, a Pledge Agreement, a Security Agreement and a Mortgage, and such other Security Instruments as either Agent or the Required Lenders may reasonably request, and (c) the delivery by the Borrower of any certificates, opinions of counsel, title opinions or other documents as and when either Agent may reasonably request; provided that, in any event, no Subsidiary may be created or acquired if a Default has occurred before or after giving effect to such creation or acquisition of the new Subsidiary. Notwithstanding the foregoing, if any Subsidiary shall cease to be an Immaterial Subsidiary for any reason, then at either Agent’s request and within the time period requested by such Agent (i) such Subsidiary shall execute and deliver a Guaranty, a Pledge Agreement, a Security Agreement and a Mortgage, and such other Security Instruments as either Agent or the Required Lenders may reasonably request, and (ii) the Borrower shall deliver certificates, opinions of counsel, title opinions or other documents as either Agent may reasonably request.

(i)      Article VI of the Credit Agreement (Negative Covenants) is hereby amended by adding a new Section 6.24 as follows:
Section 6.24     Non-Guarantor Subsidiaries . Notwithstanding anything to the contrary contained herein, including any other provision of this Article VI, no

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Loan Party shall, nor shall any Loan Party permit any of its Subsidiaries to, (a) create, assume, incur or suffer to exist any Lien on or in respect of any of its Property for the benefit of any Non-Guarantor Subsidiary, (b) sell, assign, pledge, or otherwise transfer any of its Properties (other than cash in the form of an Investment that is permitted under Section 6.06(c)) to any Non-Guarantor Subsidiary, (c) permit Non-Guarantor Subsidiaries to engage in any activity other than the acquisition of Oil and Gas Properties with the proceeds of Investments made to such Non-Guarantor Subsidiaries from the Loan Parties and other ancillary activities solely and directly related to the operation and maintenance of such Oil and Gas Properties, or (d) permit the aggregate assets or quarterly revenues of Non- Guarantor Subsidiaries to exceed 2.00% of the consolidated assets or quarterly revenues of the Borrower and its consolidated Subsidiaries, in each case, based upon the most recent financial statements available to the Borrower. In furtherance of the foregoing, each Loan Party shall (i) as to Non-Guarantor Subsidiaries, cause such Non-Guarantor Subsidiaries to transfer 100% of all its assets to a Loan Party on at least a semi-annual basis, on June 30 th and December 31 st of each year (or such later dates acceptable to the Administrative Agent in its sole discretion so long as there are at least two transfers per fiscal year under this clause (i)), and (ii) as to any Subsidiary, at any time when the value of its assets or quarterly revenues would cause such Subsidiary to cease to be an Immaterial Subsidiary, cause such Subsidiary to transfer 100% of all its assets to a Loan Party.

Section 3.      Representations and Warranties . Each Loan Party represents and warrants that: (a) after giving effect to this Agreement, the representations and warranties contained in the Credit Agreement and the representations and warranties contained in the other Loan Documents are true and correct in all material respects (except that such materiality qualifier shall not be applicable to any representations and warranties that already are qualified or modified by materiality in the text thereof) on and as of the date hereof; (b) after giving effect to this Agreement, no Default has occurred and is continuing; (c) the execution, delivery and performance of this Agreement are within the corporate, partnership, or limited liability company power and authority of such Loan Party, as applicable, and have been duly authorized by appropriate corporate, partnership, or limited liability company action and proceedings, as applicable; (d) this Agreement constitutes the legal, valid, and binding obligation of such Loan Party enforceable in accordance with its terms, except as limited by applicable bankruptcy, insolvency, reorganization, moratorium, or similar laws affecting the rights of creditors generally and general principles of equity; (e) there are no governmental or other third party consents, licenses and approvals required in connection with the execution, delivery, performance, validity and enforceability of this Agreement; (f) the Liens under the Security Instruments are valid and subsisting and secure the Secured Obligations; and (g) as to each Guarantor, it has no defenses to the enforcement of its Guaranty.
Section 4.      Conditions to Effectiveness . This Agreement and the amendments provided herein shall become effective and enforceable against the parties hereto upon the receipt by the Administrative Agent of:

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(a)      multiple original counterparts of this Agreement duly and validly executed and delivered by the Borrower, the Guarantors, the Administrative Agent, the Collateral Agent, the Issuing Lender, the Swing Line Lender, and the Required Lenders, and
(b)      an officer’s certificate from the Borrower, in form and substance satisfactory to the Administrative Agent and dated as of the Effective Date, certifying (i) true and correct copy of the merger certificate evidencing the Gastar Merger, (ii) true and correct copy of the name change or other certificate evidencing the change in the Borrower’s name to Gastar Exploration Inc., (iii) the Loan Parties’ respective officers' incumbency (or if such officers’ incumbency certified with the initial closing of the Credit Agreement have not changed, then certifying no change in such incumbency), (iv) authorizing resolutions for the Loan Parties for this Agreement (or if the authorizing resolutions delivered with the initial closing of the Credit Agreement authorized amendments thereto, then certifying no change in such authorizing resolutions), and (v) true and correct copies of the organizational documents of the Loan Parties (or if the organizational documents have not changed since the initial closing of the Credit Agreement, then certifying no change in such organizational documents).
Section 5.      Effect on Loan Documents; Acknowledgments .
(a)      The Borrower acknowledges that on the date hereof all Obligations are payable without defense, offset, counterclaim or recoupment.
(b)      The Administrative Agent, the Collateral Agent, the Issuing Lender, the Swing Line Lender, and the Lenders hereby expressly reserve all of their rights, remedies, and claims under the Loan Documents. Nothing in this Agreement shall constitute a waiver or relinquishment of (i) any Default or Event of Default under any of the Loan Documents, (ii) any of the agreements, terms or conditions contained in any of the Loan Documents, (iii) any rights or remedies of the Administrative Agent, the Collateral Agent, the Issuing Lender, the Swing Line Lender, or any Lender with respect to the Loan Documents, or (iv) the rights of the Administrative Agent, the Collateral Agent, the Issuing Lender, the Swing Line Lender, or any Lender to collect the full amounts owing to them under the Loan Documents.
(c)      Each of the Borrower, the Guarantors, the Administrative Agent, the Collateral Agent, the Issuing Lender, the Swing Line Lender, and the Lenders does hereby adopt, ratify, and confirm the Credit Agreement, as amended hereby, and acknowledges and agrees that the Credit Agreement, as amended hereby, and all other Loan Documents are and remain in full force and effect, and the Borrower acknowledges and agrees that its liabilities under the Credit Agreement and the other Loan Documents are not impaired in any respect by this Agreement.
(d)      From and after the Effective Date, all references to the Credit Agreement and the Loan Documents shall mean such Credit Agreement and such Loan Documents as amended prior hereto as described in the recitals, and by this Agreement.
(e)      This Agreement is a Loan Document for the purposes of the provisions of the other Loan Documents. Without limiting the foregoing, any breach of representations,

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warranties, and covenants under this Agreement shall be a Default or Event of Default, as applicable, under the Credit Agreement.
Section 6.      Reaffirmation of the Guaranty . Each Guarantor hereby ratifies, confirms, acknowledges and agrees that its obligations under its Guaranty are in full force and effect and that such Guarantor continues to unconditionally and irrevocably guarantee the full and punctual payment, when due, whether at stated maturity or earlier by acceleration or otherwise, of all of the Guaranteed Obligations (as defined in its Guaranty), as such Guaranteed Obligations may have been amended by this Agreement, and its execution and delivery of this Agreement does not indicate or establish an approval or consent requirement by such Guarantor under its Guaranty in connection with the execution and delivery of amendments to the Credit Agreement, the Notes or any of the other Loan Documents.
Section 7.      Counterparts . This Agreement may be signed in any number of counterparts, each of which shall be an original and all of which, taken together, constitute a single instrument. This Agreement may be executed by facsimile or email ( i.e., PDF) signature and all such signatures shall be effective as originals.
Section 8.      Successors and Assigns . This Agreement shall be binding upon and inure to the benefit of the Borrower, the Lenders, the Issuing Lender, the Swing Line Lender, the Collateral Agent, and the Administrative Agent and their respective successors and assigns permitted pursuant to the Credit Agreement.
Section 9.      Invalidity . In the event that any one or more of the provisions contained in this Agreement shall for any reason be held invalid, illegal or unenforceable in any respect, such invalidity, illegality or unenforceability shall not affect any other provision of this Agreement.
Section 10.      Governing Law . This Agreement shall be deemed a contract under, and shall be governed by, and construed and enforced in accordance with, the laws of the State of New York applicable to contracts made and to be performed entirely within such state, without regard to conflicts of laws principles (other than Section 5-1401 and Section 5-1402 of the General Obligations Law of the State of New York).
Section 11.      Waiver of Jury . THE BORROWER, THE LENDERS, THE ISSUING LENDER, AND THE AGENTS HEREBY ACKNOWLEDGE THAT THEY HAVE BEEN REPRESENTED BY AND HAVE CONSULTED WITH COUNSEL OF THEIR CHOICE, AND HEREBY KNOWINGLY, VOLUNTARILY, INTENTIONALLY, AND IRREVOCABLY WAIVE ANY AND ALL RIGHT TO TRIAL BY JURY IN RESPECT OF ANY LEGAL PROCEEDING ARISING OUT OF OR RELATING TO THIS AGREEMENT, ANY OTHER LOAN DOCUMENT, OR ANY OF THE TRANSACTIONS CONTEMPLATED HEREBY OR THEREBY.
Section 12.      Entire Agreement . THIS AGREEMENT, THE CREDIT AGREEMENT AS AMENDED BY THIS AGREEMENT, THE NOTES, AND THE OTHER LOAN DOCUMENTS CONSTITUTE THE ENTIRE UNDERSTANDING AMONG THE PARTIES

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HERETO WITH RESPECT TO THE SUBJECT MATTER HEREOF AND SUPERSEDE ANY PRIOR AGREEMENTS, WRITTEN OR ORAL, WITH RESPECT THERETO.
[The remainder of this page has been left blank intentionally.]


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Exhibit 10.1

EXECUTED effective as of the date first above written.


BORROWER :

GASTAR EXPLORATION INC.


By: /s/ Michael A. Gerlich    
Michael A. Gerlich
Senior Vice President, Chief Financial Officer and
Corporate Secretary


GUARANTORS:

GASTAR EXPLORATION NEW SOUTH WALES, INC.
GASTAR EXPLORATION TEXAS, INC.
GASTAR EXPLORATION TEXAS LLC


Each By:     /s/ Michael A. Gerlich            
Michael A. Gerlich
Senior Vice President, Secretary and
Treasurer

GASTAR EXPLORATION TEXAS, LP

By:    GASTAR EXPLORATION TEXAS LLC,
its General Partner


By:     /s/ Michael A. Gerlich            
Michael A. Gerlich
Senior Vice President, Secretary and
Treasurer

Signature Page to
Agreement, Waiver and Amendment No. 3 to
Second Amended and Restated Credit Agreement
(Gastar Exploration, Inc.)
#4498855

Exhibit 10.1

ADMINISTRATIVE AGENT/COLLATERAL AGENT/ISSUING LENDER/SWING LINE LENDER/LENDER :

WELLS FARGO BANK, NATIONAL ASSOCIATION


By: /s/Stephanie Harrell     
Stephanie Harrell
Assistant Vice President


Signature Page to
Agreement, Waiver and Amendment No. 3 to
Second Amended and Restated Credit Agreement
(Gastar Exploration, Inc.)
#4498855


Exhibit 10.1

LENDER :

COMERICA BANK


By: /s/William Robinson     
William Robinson
Vice President

Signature Page to
Agreement, Waiver and Amendment No. 3 to
Second Amended and Restated Credit Agreement
(Gastar Exploration, Inc.)
#4498855


Exhibit 10.1

LENDER :

IBERIABANK


By: /s/Cameron D. Jones     
Cameron D. Jones
Senior Vice President



Signature Page to
Agreement, Waiver and Amendment No. 3 to
Second Amended and Restated Credit Agreement
(Gastar Exploration, Inc.)
#4498855


Exhibit 10.1

LENDER :

ING CAPITAL LLC


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

By: /s/Juli Bieser     
Name: Juli Bieser
Title: Director



Signature Page to
Agreement, Waiver and Amendment No. 3 to
Second Amended and Restated Credit Agreement
(Gastar Exploration, Inc.)
#4498855

                                                

 
 
For Immediate Release
 
   NEWS RELEASE
 
Contacts:
Gastar Exploration Inc.
Michael A. Gerlich, Chief Financial Officer
713-739-1800 / mgerlich@gastar.com
 
Investor Relations Counsel:
Lisa Elliott / Anne Pearson
Dennard▪Lascar Associates: 713-529-6600
lelliott@DennardLascar.com/apearson@DennardLascar.com


GASTAR EXPLORATION INC. REPORTS
FOURTH QUARTER 2013 RESULTS
4Q revenue nearly doubles, production up 30% year over year
Liquids represent 65% of total revenue

HOUSTON, March 13, 2014 - Gastar Exploration Inc. (NYSE MKT: GST) ("Gastar") today reported financial and operating results for the three months and the year ended December 31, 2013.
Net loss attributable to Gastar’s common stockholders for the fourth quarter of 2013 was $3.3 million, or a loss of $0.06 per share. Excluding the impact of a $2.8 million loss resulting from the mark-to-market of outstanding hedge positions at December 31, 2013 and non-recurring corporate restructuring charges of $1.2 million, adjusted net income attributable to common stockholders was $0.7 million, or $0.01 per diluted share.
This compares to fourth quarter 2012 net income of $2.9 million, or $0.05 per diluted share, and adjusted net income of $4.6 million, or $0.07 per diluted share, excluding the impact of a $1.4 million loss resulting from the mark-to-market of outstanding hedge positions at December 31, 2012 and non-recurring charges of $206,000. (See the accompanying reconciliation of net income (loss) to net income (loss) excluding special items at the end of this news release.)
Adjusted earnings before interest, income taxes, depreciation, depletion and amortization ("adjusted EBITDA") for the fourth quarter of 2013 was $21.2 million, or $0.35 per diluted share, an increase of 59% compared to adjusted EBITDA of $13.4 million, or $0.21 per diluted share, for the fourth quarter of 2012 and a 24% increase over adjusted third quarter 2013 results. (See the accompanying reconciliation of net income (loss) to adjusted EBITDA at the end of this news release.)
Natural gas, oil, condensate and natural gas liquids (NGLs) revenues before the impact of hedging activities increased 99% to $29.2 million in the fourth quarter of 2013, up from $14.7 million for the same

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period of 2012. The increase was primarily the result of 30% growth in production volumes and a 53% increase in the weighted average sales price per thousand cubic feet of natural gas equivalent (Mcfe) before the positive impact of commodity derivative contracts settled during the period. Revenues from liquids (oil, condensate and NGLs) represented approximately 65% of our total production revenues for the fourth quarter of 2013 compared to 58% for the third quarter of 2013 and 44% for the fourth quarter of 2012. Commodity derivative contracts settled during the periods resulted in additional revenues for the fourth quarter of 2013 and 2012 of $288,000 and $4.1 million, respectively.
Average daily production was 55.2 million cubic feet of natural gas equivalent per day (MMcfe/d), or 9,200 barrels of oil equivalent per day (Boe/d), for the fourth quarter of 2013, a 30% increase compared to 42.5 MMcfe/d (7,080 Boe/d) for the same period in 2012. Oil, condensate and NGLs as a percentage of production volumes was 39% in the fourth quarter of 2013 compared to 24% in the fourth quarter of 2012. Higher year-over-year production volumes were primarily driven by our horizontal drilling activity in the Marcellus Shale and Hunton Limestone as well as the acquisition of producing assets in the Mid-Continent, partially offset by the sale of producing assets in East Texas. Sequentially, average daily production decreased 7% due to the sale of East Texas assets on October 2, 2013, partially offset by new Hunton well completions and production from our WEHLU acquisition in Oklahoma which closed on November 15, 2013.   Oil, condensate and NGLs as a percentage of production volumes increased 10% sequentially.
The following table provides a summary of Gastar’s production volumes and average commodity prices for the three-months and years ended December 31, 2013 and 2012:


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For the Three Months Ended December 31,
 
For the Years Ended December 31,
 
 
2013
 
2012
 
2013
 
2012
 
 
 
 
 
 
 
 
 
Production:
 
 
 
 
 
 
 
 
Natural gas (MMcf)
 
3,108

 
2,980

 
13,366

 
10,564

Oil and condensate (MBbl)
 
182

 
71

 
515

 
177

NGLs (MBbl)
 
147

 
84

 
494

 
270

Total production by equivalent:
 
 
 
 
 
 
 
 
MMcfe
 
5,080

 
3,908

 
19,417

 
13,247

MBoe
 
847

 
651

 
3,236

 
2,208

 
 
 
 
 
 
 
 
 
Average daily production by equivalent:
 
 
 
 
 
 
 
 
MMcfe/d
 
55.2

 
42.5

 
53.2

 
36.2

MBoe/d
 
9.2

 
7.1

 
8.9

 
6.0

 
 
 
 
 
 
 
 
 
Average sales price per unit:
 
 
 
 
 
 
 
 
Natural gas per Mcf, including impact of hedging (1)
 
$
3.58

 
$
3.80

 
$
3.43

 
$
3.20

Natural gas per Mcf, excluding impact of hedging (1)
 
$
3.31

 
$
2.77

 
$
3.02

 
$
2.21

Oil and condensate per Bbl, including impact of hedging (1)
 
$
75.62

 
$
65.61

 
$
71.04

 
$
70.01

Oil and condensate per Bbl, excluding impact of hedging (1)
 
$
75.75

 
$
60.19

 
$
70.91

 
$
65.45

NGLs per Bbl, including impact of hedging (1)
 
$
31.93

 
$
34.59

 
$
31.13

 
$
34.40

NGLs per Bbl, excluding impact of hedging (1)
 
$
35.34

 
$
26.46

 
$
31.59

 
$
28.22

 
 
 
 
 
 
 
 
 
Average sales price per Mcfe, including impact of hedging (1)
 
$
5.81

 
$
4.83

 
$
5.03

 
$
4.19

Average sales price per Mcfe, excluding impact of hedging (1)
 
$
5.76

 
$
3.77

 
$
4.76

 
$
3.21

Average sales price per Boe, including impact of hedging (1)
 
$
34.89

 
$
28.97

 
$
30.20

 
$
25.14

Average sales price per Boe, excluding impact of hedging (1)
 
$
34.55

 
$
22.61

 
$
28.58

 
$
19.26

_____________________________
(1) The impact of hedging is defined as the gain (loss) on commodity derivative contracts settled during the period.

We had natural gas price hedges in place covering approximately 76% of natural gas production and oil price hedges covering approximately 82% of our combined oil, condensate and NGLs production for the fourth quarter of 2013. We continue to maintain an active hedging program covering a portion of our estimated future production, which is reported in our periodic filings with the U.S. Securities and Exchange Commission (SEC).
Lease operating expense (LOE) was $3.3 million for the fourth quarter of 2013, compared to $1.4 million in the fourth quarter of 2012 and $2.2 million in the third quarter of 2013. The increase in LOE compared to the prior-year period was primarily due to the additional expenses associated with the Chesapeake acquisition, the oil dominated WEHLU acquisition and with higher overall costs associated with producing higher-value oil versus natural gas. LOE per Boe of production increased to $3.85 in the fourth quarter of 2013 from $2.18 in the fourth quarter of 2012 and $2.41 in the third quarter of 2013.

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Depreciation, depletion and amortization (DD&A) was $11.0 million in the fourth quarter of 2013, up from $5.7 million in the prior-year period and $8.5 million in the third quarter of 2013. The year-over-year increase in DD&A expense was the result of the purchase of the WEHLU oil producing properties in Oklahoma. The DD&A rate for the fourth quarter of 2013 was $13.02 per Boe compared to $8.72 per Boe for the same period in 2012 and $9.31 in the third quarter of this year.
General and administrative (G&A) expense was $5.0 million in the fourth quarter of 2013, compared to $2.9 million in the prior-year period. G&A expense for the most recent quarter included $1.2 million of non-recurring expenses related to acquisitions and to the reorganization to eliminate Gastar's holding company corporate structure and $895,000 of non-cash, stock-based compensation expense; whereas the prior-year period included $206,000 related to the reorganization of Gastar's corporate structure and $720,000 for stock-based compensation. Excluding these items, recurring cash G&A expense increased to $2.9 million for the fourth quarter of 2013 compared to $2.0 million in the fourth quarter of 2012. The increase in 2013 recurring cash G&A expense was primarily related to additional staff costs associated with the operation and administration of our growing property base.
With the completion of the Chesapeake acquisition asset valuation during the fourth quarter of 2013, the gain on acquisition of assets at fair value was reduced by the application of a deferred tax liability of $16.0 million resulting in the presentation of a fourth quarter 2013 fair market value loss. This was directly offset by the recognition of a corresponding deferred income tax benefit of $16.0 million arising from the resulting decrease in our valuation allowance for deferred tax assets.
Interest expense totaled $5.6 million in the fourth quarter of 2013, compared with $184,000 in the fourth quarter of 2012. The increase was the result of the issuance in 2013 of $325 million aggregate principal amount of new 8 5/8% Senior Secured Notes Due 2018.
J. Russell Porter, Gastar's President and CEO, stated, “Gastar’s fourth quarter results partially reflect the benefits of our recent acquisitions and divestitures, which resulted in a more favorable production mix with 39% of total volumes comprised of higher-value liquids. As a result, revenue from production and adjusted EBITDA were up sharply quarter over quarter, as well as year over year. We believe our recent acquisitions will result in significant future production growth that will yield solid returns going forward.
“We made progress during the fourth quarter toward de-risking and delineating the oil potential of our operated Hunton acreage in Oklahoma. Our first three operated wells were spread broadly across our 126,000 net-acre position, and all encountered oil in the Lower Hunton formation. We believe the Lower Hunton will be a statistical play and should provide average results consistent with our published type

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curves. While our first two operated wells are currently producing at rates below our type curve, we believe this is due to mechanical and operational complications related to the highly fractured nature of the Hunton in the areas where these wells were drilled as we encountered more fractures and larger fractures within these wells than previously found in our non-operated Hunton Area of Mutual Interest (AMI). Our third operated well was placed on flow-back last week and results should be known during the second quarter of 2014.”
“The first well drilled on our newly acquired WEHLU acreage will spud in April to test the Lower Hunton, followed immediately by the spudding of an Upper Hunton WEHLU well test. On our non-operated Hunton AMI acreage, the operator is continuing to run two rigs, which should drive steady increases in our crude oil production.”
“In addition to the Hunton potential on our 126,000 net acre position, we also believe that a meaningful amount of our acreage will be prospective for development of the Woodford Shale and Meramec Mississippian formations. We have not yet attempted to catalog the potential related to these additional development targets.”
“In Appalachia, we are ramping up activity and plan to place at least 13 Marcellus wells on production during the remainder of this year. We are also in the final stages of completing acreage trades with other operators in the area that when completed will substantially increase our future Marcellus and Utica drilling locations. We have identified 73 incremental drilling locations, including locations related to pending acreage trades, in our liquids-rich gas area, and we now have a total of 112 Marcellus Shale drilling locations identified for future development in Marshall and Wetzel Counties, West Virginia.”
“We plan to spud our first Utica Shale test well in early April, and we are highly encouraged by the results of several other operators in close proximity to our acreage. Based on the nearby activity, we believe that the Utica underlies all of our acreage in Marshall and Wetzel counties, providing Gastar with an estimated 114 gross Utica drilling locations based on 1000-foot spacing between wells. Although this is in the dry gas window of the Utica, the high production rates of nearby operators indicate that each well could contain significant recoverable reserves, providing very attractive individual well returns as well as the ability to meaningfully increase Gastar’s per share net asset value,” concluded Porter.
Operations Review and Update
Appalachia
Net production from the Marcellus Shale area averaged 41.0 MMcfe/d (6,830 Boe/d) in the fourth quarter of 2013, compared to 29.9 MMcfe/d (4,990 Boe/d) for the fourth quarter of 2012 and 43.0 MMcfe/d (7,160 Boe/d) in the third quarter of 2013. Our liquids-rich gas production, on average, yielded

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approximately 30 barrels of condensate and 52 barrels of NGLs per million cubic feet (MMcf) of natural gas sold during for the fourth quarter of 2013
During October 2013, Marcellus production was negatively impacted by a leak in the third-party operated pipeline which resulted in an estimated loss of approximately 1.3 MMcfe/d of net production for the fourth quarter of 2013. Beyond this isolated issue, it appears that substantially all of the midstream-related curtailment issues we experienced in 2013 have been resolved.
We had 57 gross (27.0 net) operated wells on production in Marshall County, West Virginia during the fourth quarter of 2013, and no additional wells were completed during the period. In 2014, to develop the Marcellus Shale, we are operating a smaller rig to drill the vertical top section of wells and a larger rig to drill the horizontal lateral sections. In late February 2014, we completed drilling the top-hole sections of nine wells on the Armstrong pad and expect to drill the lateral, complete and begin producing five of those wells in the third quarter of 2014. Top-hole drilling recently commenced at the Hansen pad, where five wells are planned and are expected to be placed on production in the fourth quarter of 2014.
We anticipate our next three Marcellus Shale wells will be placed on production late in the second quarter of 2014 from our Goudy pad in Marshall County, West Virginia. We expect total gross operated wells on production in the area to be approximately 71 by year-end 2014.
Net capital expenditures in the Marcellus Shale for the fourth quarter of 2013 totaled $7.9 million. As previously announced, we have budgeted for capital expenditures in Appalachia totaling $68 million in 2014, of which $54 million is for drilling and completion, $9 million is for acreage costs and $5 million is for infrastructure costs.
Mid-Continent
Net production from the Mid-Continent area averaged 14.1 MMcfe/d (2,350 Boe/d) in the fourth quarter of 2013, compared to 0.1 MMcfe/d (20 Boe/d) for the fourth quarter of 2012 and 7.0 MMcfe/d (1,170 Boe/d) in the third quarter of 2013. Our fourth quarter 2013 Mid-Continent production consisted of approximately 49% oil, 43% natural gas and 8% NGLs, yielding a liquids to total equivalent production percentage of 57%.
At December 31, 2013, we held leases covering approximately 209,100 gross (126,000 net) acres in Major, Garfield, Canadian, Kingfisher, Logan, Blaine and Oklahoma Counties, Oklahoma within the Hunton Limestone horizontal oil play.
Our first three operated wells have been completed and placed on production. The Burton 16-1H started flowback in early December 2013 and achieved peak production of 111 Boe/d (65% oil) in January 2014.

6



The Townsend 06-1H started flowback in early January 2014 and production is continuing to increase with its most recently reported five-day production average rate at 271 Boe/d (53% oil). The wells continue to flow back completion fluid at a combined average rate of approximately 600 barrels per day. The Taborek 22-1H was completed using a different completion technique in order to minimize reservoir damage and flowback has just commenced.
Within the Hunton AMI, Gastar participated in two gross (1.0 net) non-operated wells that were completed and placed on production during the fourth quarter of 2013. The previously announced Mid-Con 6H and 7H wells average initial production rates were 1,442 (86% oil) and 906 (72% oil) Boe/d, respectively, and the most recent 10-day average production was 852 (45% oil) and 123 (50% oil) Boe/d, respectively. The Mid-Con 7H, which flowed naturally for approximately three months, was just recently placed on gas lift and operations are in process to calibrate artificial lift and maximize production flow. Subsequent to year-end, two gross (1.0 net) non-operated wells were placed on production and four gross (1.7 net) wells within the AMI are in various stages of completion or drilling.
During the first quarter of 2014, we anticipate three gross (1.1 net) non-operated AMI wells and one gross (0.9 net) operated well being placed on production.
In the Mid-Continent, net capital expenditures in the fourth quarter of 2013, excluding acquisition costs and divestment proceeds, totaled $25.1 million. We expect to spend approximately $114 million during 2014 on our Mid-Continent play, of which approximately $87 million is for drilling and completion related expenses.
Guidance for the First Quarter of 2014
We are reaffirming previously issued guidance for the full-year 2014 and providing the following guidance for the first quarter of 2014:
Production
First Quarter 2014
 
Full-Year 2014
 
 
 
 
Net average daily (MBoe/d) (1)
9.3 - 9.7
 
9.7 - 11.0
Liquids percentage
39% - 41%
 
40% - 44%
 
 
 
 
Cash Operating Expenses ($ / Boe)
First Quarter 2014
 
Full-Year 2014
Production taxes
$2.10 - $2.30
 
$1.95 - $2.25
Direct lease operating
$4.65 - $5.10
 
$4.55 - $5.10
Transportation, treating & gathering
$0.70 - $0.80
 
$0.60 - $0.65
Cash general & administrative
$3.40 - $3.70
 
$2.90 - $3.20
________________
(1) Based on equivalent of 6 thousand cubic feet (Mcf) of natural gas to one barrel of oil, condensate or NGLs.

7



Liquidity
At December 31, 2013 we had $32.4 million in available cash and an undrawn $100 million revolving credit facility. We expect to fund our 2014 capital program through existing cash balances, internally generated cash flow from operating activities, borrowings under the revolving credit facility, possible divestiture of assets and the possible issuance of debt or equity securities or some combination thereof.
2013 Proved Reserves
As previously reported, proved reserves as of December 31, 2013 increased by 81% to 327.8 Bcfe (54.6 MMBoe), composed of 14.7 million barrels of crude oil and condensate, 9.8 million barrels of natural gas liquids and 180.7 Bcf of natural gas. Of the total proved reserves, 45% are liquids and 57% are classified as proved developed. The pre-tax SEC-priced present value of future cash flows of these reserves, discounted at 10% ("PV-10") (a non-GAAP financial measure defined below in Information on Reserves and PV-10 Value), grew 187% to $592.5 million as compared to year-end 2012.
The year-over-year net increase in proved reserves consisted of:
92.9 Bcfe (15.5 MMBoe) of proved reserve additions (pre-tax PV-10 value of $196.4 million); plus 
87.8 Bcfe (14.6 MMBoe) of proved reserves purchased (pre-tax PV-10 value of $247.2 million); plus
10.4 Bcfe (1.7 MMBoe) of positive performance and price revisions; less 
24.8 Bcfe (4.1 MMBoe) of proved reserves that were divested in 2013.
We replaced 857% of production from all sources including reserve additions from drilling activity, price and performance revisions, and proved acquisitions less divestments. We replaced 532% of production through drilling activity and price and performance revisions. Capital expenditures for 2013 totaled $292.5 million, comprised of $24.0 million for unproved acreage and related costs, $90.0 million for drilling expenditures and $178.5 million for property acquisition costs. Acquisition costs are net of proceeds of $58.6 million received for the sale of certain unproven properties acquired in the Chesapeake acquisition.

8



Conference Call
Gastar has scheduled a conference call for 10:00 a.m. Eastern Time (9:00 a.m. Central Time) tomorrow.  Investors may participate in the call either by phone or audio webcast.
By Phone:
Dial 1-888-450-9962 at least 10 minutes before the call. A telephone replay will be available through March 21 by dialing 1-800-804-7944 and using the conference ID 41261.
 
 
By Webcast:
Visit the Investor Relations page of Gastar's website at  www.gastar.com . Please log on at least 10 minutes in advance to register and download any necessary software. A replay will be available shortly after the call.


For more information, please contact Donna Washburn at Dennard-Lascar Associates at 713-529-6600 or e-mail  dwashburn@DennardLascar.com .
About Gastar
Gastar Exploration Inc. is an independent energy company engaged in the exploration, development and production of oil, natural gas, condensate and natural gas liquids in the United States. Gastar's principal business activities include the identification, acquisition, and subsequent exploration and development of oil and natural gas properties with an emphasis on unconventional reserves such as shale resource plays. Gastar is currently pursuing the development of liquids-rich natural gas in the Marcellus Shale in West Virginia and is also in the early stages of exploring and developing the Hunton Limestone horizontal oil play in Oklahoma. For more information, visit Gastar's website at www.gastar.com .
Information on Reserves and PV-10 Value
For the years ended December 31, 2013 and 2012 future cash inflows were computed using the 12-month un-weighted arithmetic average of the first-day-of-the-month prices for natural gas and oil (the "benchmark base prices") adjusted by lease in accordance with sales contracts and for energy content, quality, transportation, compression and gathering fees and regional price differentials, relating to the Company's proved reserves. Benchmark base prices are held constant in accordance with SEC guidelines for the life of the wells but are adjusted by lease in accordance with sales contracts and for energy content, quality, transportation, compression, and gathering fees and regional price differentials. PV-10 Value is a non-GAAP measure and is different than the Standardized Measure of Discounted Future Net Cash Flows ("Standardized Measure"), which measure totals $515.8 million and will be

9



presented in Gastar's upcoming Form 10-K, in that PV-10 Value is a pre-tax number, while the Standardized Measure includes the effect of estimated future income taxes.
The Company's 2013 year-end total proved reserves estimates were prepared by Wright & Company, Inc.
Forward Looking Statements
This news release includes “forward looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Forward looking statements give our current expectations, opinion, belief or forecasts of future events and performance. A statement identified by the use of forward looking words including “may,” “expects,” “projects,” “anticipates,” “plans,” “believes,” “estimate,” “will,” “should,” and certain of the other foregoing statements may be deemed forward-looking statements. Although Gastar believes that the expectations reflected in such forward-looking statements are reasonable, these statements involve risks and uncertainties that may cause actual future activities and results to be materially different from those suggested or described in this news release. These include risks inherent in natural gas and oil drilling and production activities, including risks of fire, explosion, blowouts, pipe failure, casing collapse, unusual or unexpected formation pressures, environmental hazards, and other operating and production risks, which may temporarily or permanently reduce production or cause initial production or test results to not be indicative of future well performance or delay the timing of sales or completion of drilling operations; delays in receipt of drilling permits; risks with respect to natural gas and oil prices, a material decline in which could cause Gastar to delay or suspend planned drilling operations or reduce production levels; risks relating to the availability of capital to fund drilling operations that can be adversely affected by adverse drilling results, production declines and declines in natural gas and oil prices; risks relating to unexpected adverse developments in the status of properties; borrowing base redeterminations by our banks; risks relating to the absence or delay in receipt of government approvals or fourth party consents; risks relating to our ability to integrate acquired assets with ours and to realize the anticipated benefits from such acquisitions; and other risks described in Gastar’s Annual Report on Form 10-K and other filings with the U.S. Securities and Exchange Commission (SEC), available at the SEC’s website at www.sec.gov. Our actual sales production rates can vary considerably from tested initial production rates depending upon completion and production techniques and our primary areas of operations are subject to natural steep decline rates. By issuing forward looking statements based on current expectations, opinions, views or beliefs, Gastar has no obligation and, except as required by law, is not undertaking any obligation, to update or revise these statements or provide any other information relating to such statements.

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Unless otherwise stated herein, equivalent volumes of production and reserves are based upon an energy equivalent ratio of six Mcf of natural gas to each barrel of liquids (oil, condensate and NGLs), which ratio is not reflective of relative value. Our NGLs are sold as part of our wet gas subject to an incremental NGLs pricing formula based upon a percentage of NGLs extracted from our wet gas production. Our reported production volumes reflect incremental post-processing NGLs volumes and residual gas volumes with which we are credited under our sales contracts.
Gastar’s capital budget is subject to revision and reevaluation dependent upon future developments including drilling results, availability of crews, supplies and production capacity, weather delays, significant changes in commodities prices or drilling costs.


- Financial Tables Follow -


11



GASTAR EXPLORATION, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS

 
For the Three Months Ended December 31,
 
For the Years Ended December 31,
 
2013
 
2012
 
2013
 
2012
 
(in thousands, except share and per share data)
REVENUES:
 
 
 
 
 
 
 
Natural gas
$
10,303

 
$
8,254

 
$
40,416

 
$
23,318

Oil and condensate
13,749

 
4,247

 
36,480

 
11,570

NGLs
5,196

 
2,223

 
15,611

 
7,630

Total natural gas, condensate and oil and NGLs revenues
29,248

 
14,724

 
92,507

 
42,518

(Loss) gain on commodity derivatives contracts
(2,523
)
 
2,698

 
(4,752
)
 
7,422

Total revenues
26,725

 
17,422

 
87,755

 
49,940

EXPENSES:
 
 
 
 
 
 
 
Production taxes
1,539

 
775

 
4,651

 
2,269

Lease operating expenses
3,260

 
1,420

 
9,456

 
6,174

Transportation, treating and gathering
620

 
1,250

 
4,006

 
4,965

Depreciation, depletion and amortization
11,021

 
5,680

 
32,449

 
25,424

Impairment of natural gas and oil properties

 

 

 
150,787

Accretion of asset retirement obligation
110

 
104

 
468

 
388

General and administrative expense
4,997

 
2,948

 
16,961

 
12,211

Litigation settlement expense

 

 
1,000

 
1,250

Total expenses
21,547

 
12,177

 
68,991

 
203,468

INCOME (LOSS) FROM OPERATIONS
5,178

 
5,245

 
18,764

 
(153,528
)
OTHER INCOME (EXPENSE):
 
 
 
 
 
 
 
(Loss) gain on acquisition of assets at fair value
(16,042
)
 

 
27,670

 

Interest expense
(5,575
)
 
(184
)
 
(13,168
)
 
(270
)
Investment income and other
32

 
3

 
48

 
9

Foreign transaction gain (loss)
1

 

 
(14
)
 
(2
)
(LOSS) INCOME BEFORE PROVISION FOR INCOME TAXES
(16,406
)
 
5,064

 
33,300

 
(153,791
)
Income tax benefit
(16,042
)
 

 
(16,042
)
 

NET (LOSS) INCOME
(364
)
 
5,064

 
49,342

 
(153,791
)
Dividends on preferred stock attributable to non-controlling interest
(2,980
)
 
(2,130
)
 
(9,378
)
 
(7,077
)
NET (LOSS) INCOME ATTRIBUTABLE TO GASTAR EXPLORATION, INC.
$
(3,344
)
 
$
2,934

 
$
39,964

 
$
(160,868
)
NET (LOSS) INCOME PER COMMON SHARE ATTRIBUTABLE TO GASTAR EXPLORATION, INC. COMMON STOCKHOLDERS:
 
 
 
 
 
 
 
Basic
$
(0.06
)
 
$
0.05

 
$
0.66

 
$
(2.53
)
Diluted
$
(0.06
)
 
$
0.05

 
$
0.63

 
$
(2.53
)
WEIGHTED AVERAGE SHARES OF COMMON STOCK OUTSTANDING:
 
 
 
 
 
 
 
Basic
57,433,550

 
63,669,744

 
60,220,115

 
63,538,362

Diluted
57,433,550

 
63,678,597

 
63,618,401

 
63,538,362


12



GASTAR EXPLORATION, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
 
December 31,
 
2013
 
2012
 
(in thousands, except share data)
ASSETS
 
 
 
CURRENT ASSETS:
 
 
 
Cash and cash equivalents
$
32,393

 
8,901

Accounts receivable, net of allowance for doubtful accounts of $507 and $546, respectively
21,656

 
9,540

Commodity derivative contracts

 
7,799

Prepaid expenses
1,145

 
1,097

Total current assets
55,194

 
27,337

 
 
 
 
PROPERTY, PLANT AND EQUIPMENT:
 
 
 
Oil and natural gas properties, full cost method of accounting:
 
 
 
Unproved properties, excluded from amortization
96,220

 
67,892

Proved properties
935,773

 
671,193

Total oil and natural gas properties
1,031,993

 
739,085

Furniture and equipment
2,691

 
1,925

Total property, plant and equipment
1,034,684

 
741,010

Accumulated depreciation, depletion and amortization
(517,171
)
 
(484,759
)
Total property, plant and equipment, net
517,513

 
256,251

 
 
 
 
OTHER ASSETS:
 
 
 
Commodity derivative contracts
7,545

 
1,369

Deferred charges, net
2,950

 
836

Advances to operators and other assets
6,733

 
4,275

Total other assets
17,228

 
6,480

TOTAL ASSETS
$
589,935

 
290,068

 
 
 
 
LIABILITIES AND STOCKHOLDERS' EQUITY
 
 
 
CURRENT LIABILITIES:
 
 
 
Accounts payable
$
11,046

 
$
23,863

Revenue payable
12,514

 
8,801

Accrued interest
3,504

 
151

Accrued drilling and operating costs
8,756

 
3,907

Advances from non-operators
9,259

 
17,540

Commodity derivative contracts
3,403

 
1,399

Commodity derivative premium payable
145

 

Asset retirement obligation
633

 
358

Other accrued liabilities
4,844

 
1,493

Total current liabilities
54,104

 
57,512

 
 
 
 
LONG-TERM LIABILITIES:
 
 
 
Long-term debt
312,994

 
98,000

Commodity derivative contracts
378

 
1,304

Commodity derivative premium payable
7,000

 

Asset retirement obligation
5,430

 
6,605

Other long-term liabilities

 
111

Total long-term liabilities
325,802

 
106,020

 
 
 
 
Commitments and contingencies
 
 
 
 
 
 
 
STOCKHOLDERS' EQUITY:
 
 
 
Common stock, $0.001 par value; 275,000,000 shares authorized; 61,211,658 and 66,432,609 shares issued and outstanding at December 31, 2013 and 2012, respectively; no par value at December 31, 2012
61

 
316,346

Additional paid-in capital
337,969

 
28,336

Accumulated deficit
(254,823
)
 
(294,787
)
Total stockholders' equity
83,207

 
49,895

Non-controlling interest:


 


Preferred stock of subsidiary, aggregate liquidation preference $152,454 and $98,781 at December 31, 2013 and 2012, respectively
126,822

 
76,641

Total equity
210,029

 
126,536

TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY
$
589,935

 
$
290,068


13



GASTAR EXPLORATION, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
 
For the Years Ended December 31,
 
2013
 
2012
 
(in thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
 
 
 
Net income (loss)
$
49,342

 
$
(153,791
)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
 
 
 
Depreciation, depletion and amortization
32,449

 
25,424

Impairment of natural gas and oil properties

 
150,787

Stock-based compensation
3,435

 
3,295

Mark to market of commodity derivatives contracts:
 
 
 
Total loss (gain) on commodity derivatives contracts
4,752

 
(7,422
)
Cash settlements of matured commodity derivatives contracts, net
5,892

 
16,251

Cash premiums paid for commodity derivatives contracts
(152
)
 
(4,539
)
Amortization of deferred financing costs
2,322

 
224

Accretion of asset retirement obligation
468

 
388

Settlement of asset retirement obligation
(66
)
 
(636
)
Gain on acquisition of assets at fair value
(27,670
)
 

Deferred tax benefit
(16,042
)
 

Changes in operating assets and liabilities:
 
 
 
Accounts receivable
(8,431
)
 
2,487

Prepaid expenses
(48
)
 
146

Accounts payable and accrued liabilities
1,563

 
4,441

Net cash provided by operating activities
47,814

 
37,055

CASH FLOWS FROM INVESTING ACTIVITIES:
 
 
 
Development and purchase of oil and natural gas properties
(95,343
)
 
(136,311
)
Advances to operators
(22,213
)
 
(9,649
)
Acquisition of oil and natural gas properties
(251,096
)
 

Proceeds from sale of oil and natural gas properties
112,201

 

(Use of proceeds) proceeds from non-operators
(8,281
)
 
(1,983
)
Purchase of furniture and equipment
(766
)
 
(296
)
Net cash used in investing activities
(265,498
)
 
(148,239
)
CASH FLOWS FROM FINANCING ACTIVITIES:
 
 
 
Repurchase of common stock
(9,753
)
 

Proceeds from revolving credit facility
19,000

 
98,000

Repayment of revolving credit facility
(117,000
)
 
(30,000
)
Proceeds from issuance of senior secured notes, net of discount
312,279

 

Proceeds from issuance of preferred stock, net of issuance costs
50,183

 
49,250

Dividends on preferred stock attributable to non-controlling interest
(9,378
)
 
(7,077
)
Deferred financing charges
(3,785
)
 
(450
)
Other
(370
)
 
(285
)
Net cash provided by financing activities
241,176

 
109,438

NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
23,492

 
(1,746
)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD
8,901

 
10,647

CASH AND CASH EQUIVALENTS, END OF PERIOD
$
32,393

 
$
8,901





14





NON-GAAP FINANCIAL INFORMATION AND RECONCILIATION

We use both GAAP and certain non-GAAP financial measures to assess performance. Generally, a non-GAAP financial measure is a numerical measure of a company’s performance, financial position or cash flows that either excludes or includes amounts that are not normally excluded or included in the most directly comparable measure calculated and presented in accordance with GAAP. Our management believes that these non-GAAP measures provide useful supplemental information to investors in order that they may evaluate our financial performance using the same measures as management. These non-GAAP financial measures should not be considered as a substitute for, or superior to, measures of financial performance prepared in accordance with GAAP. In evaluating these measures, investors should consider that the methodology applied in calculating such measures may differ among companies and analysts. A reconciliation is provided below outlining the differences between these non-GAAP measures and the directly related GAAP measures.

Reconciliation of Net Income (Loss) to Net Income (Loss) Excluding Special Items:
 
For the Three Months Ended December 31,
 
For the Years Ended December 31,
 
2013
 
2012
 
2013
 
2012
 
(in thousands, except share and per share data)
 
 
 
 
 
 
 
 
NET (LOSS) INCOME ATTRIBUTABLE TO GASTAR EXPLORATION, INC. AS REPORTED
$
(3,344
)
 
$
2,934

 
$
39,964

 
$
(160,868
)
SPECIAL ITEMS:
 
 
 
 
 
 
 
Losses related to the change in mark to market value for outstanding commodity derivatives contracts
2,811

 
1,443

 
9,967

 
5,566

Impairment of natural gas and oil properties

 

 

 
150,787

Non-recurring general and administrative costs related to acquisition of assets
639

 

 
2,349

 

Non-recurring general and administrative costs related to Parent migration
593

 
206

 
1,196

 
834

Non-recurring severance costs related to property divestment

 

 
659

 

Non-recurring stock compensation benefit related to property divestment

 

 
(422
)
 

Litigation settlement expense

 

 
1,000

 
1,250

Loss (gain) on acquisition of assets at fair value
16,042

 

 
(27,670
)
 

Write off of fees associated with Old Amended Revolving Credit Facility

 

 
1,154

 

Foreign transaction (gain) loss
(1
)
 

 
14

 
2

Income tax benefit
(16,042
)
 

 
(16,042
)
 

 
 
 
 
 
 
 
 
ADJUSTED NET INCOME (LOSS) ATTRIBUTABLE TO GASTAR EXPLORATION, INC.
$
698

 
$
4,583

 
$
12,169

 
$
(2,429
)
 
 
 
 
 
 
 
 
ADJUSTED NET INCOME (LOSS) PER SHARE ATTRIBUTABLE TO GASTAR EXPLORATION, INC. COMMON STOCKHOLDERS:
 
 
 
 
 
 
 
Basic
$
0.01

 
$
0.07

 
$
0.20

 
$
(0.04
)
Diluted
$
0.01

 
$
0.07

 
$
0.19

 
$
(0.04
)
 
 
 
 
 
 
 
 
WEIGHTED AVERAGE SHARES OF COMMON STOCK OUTSTANDING:
 
 
 
 
 
 
 
Basic
57,433,550

 
63,669,744

 
60,220,115

 
63,538,362

Diluted
61,248,076

 
63,678,597

 
63,618,401

 
63,538,362

 
 
 
 
 
 
 
 


15



Reconciliation of Net Income (Loss) to Adjusted Earnings Before Interest, Income Taxes, Depreciation, Depletion and Amortization ("Adjusted EBITDA"):
 
For the Three Months Ended December 31,
 
For the Years Ended December 31,
 
2013
 
2012
 
2013
 
2012
 
(in thousands, except share and per share data)
 
 
 
 
 
 
 
 
NET (LOSS) INCOME ATTRIBUTABLE TO GASTAR EXPLORATION, INC. AS REPORTED
$
(3,344
)
 
$
2,934

 
$
39,964

 
$
(160,868
)
Interest expense
5,575

 
184

 
13,168

 
270

Dividend expense
2,980

 
2,130

 
9,378

 
7,077

Depreciation, depletion and amortization
11,021

 
5,680

 
32,449

 
25,424

Accretion of asset retirement obligation
110

 
104

 
468

 
388

Impairment of natural gas and oil properties

 

 

 
150,787

Loss (gain) on acquisition of assets at fair value
16,042

 

 
(27,670
)
 

Losses related to the change in mark to market value for outstanding commodity derivatives contracts
2,811

 
1,443

 
9,967

 
5,566

Non-cash stock compensation expense
895

 
720

 
3,435

 
3,295

Litigation settlement expense

 

 
1,000

 
1,250

Foreign transaction (gain) loss
(1
)
 

 
14

 
2

Interest income and other
(32
)
 
(3
)
 
(48
)
 
(9
)
Non-recurring general and administrative costs related to acquisition of assets
639

 

 
2,349

 

Non-recurring general and administrative costs related to Parent migration
593

 
206

 
1,196

 
834

Non-recurring severance costs related to property divestment

 

 
659

 

Income tax benefit
(16,042
)
 

 
(16,042
)
 

Adjusted EBITDA
$
21,247

 
$
13,398

 
$
70,287

 
$
34,016

 
 
 
 
 
 
 
 


# # #


16