Edgar Filing: GASTAR EXPLORATION LTD

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Amendment No. 1 to Form 10-Q for quarterly period ended March 31, 2010

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q/A

(Amendment No. 1)

x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2010

¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 FOR THE TRANSITION PERIOD FROM TO .

Commission File Number: 001-32714

GASTAR EXPLORATION LTD.

(Exact name of registrant as specified in its charter)


Alberta, Canada		98-0570897
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

1331 Lamar Street, Suite 1080 Houston, Texas 77010		77010
(Address of principal executive offices)		(ZIP Code)

(713) 739-1800

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ¨ No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No x

Total number of outstanding common shares, no par value per share, as of May 4, 2010 was 50,399,695.

EXPLANATORY NOTE

Gastar Exploration Ltd. (“Gastar”, “we” or the “Company”) is filing this Amendment No. 1 on Form 10-Q/A (this “Amendment”) to our Quarterly Report on Form 10-Q for the period ended March 31, 2010 (the “Form 10-Q”), originally filed with the Securities and Exchange Commission (the “SEC”) on May 6, 2010. This Amendment is being filed to amend and restate our unaudited condensed consolidated financial statements as of and for the three months ended March 31, 2010 for the reasons stated below.

In conjunction with its review of our results of operations and hedging in connection with the quarterly review at June 30, 2010, management discovered that at March 31, 2010, the commodity derivative premium payable was inappropriately netted with the receivables from commodity derivative contracts resulting in an incorrect marked to market value for commodity derivative assets and understated unrealized natural gas hedge gains for the period. As a result of its analysis of the accounting error, management determined that the current receivables from commodity derivative contracts, the long-term receivables from commodity derivative contracts and the unrealized natural gas hedge gain were understated by $1.9 million, $7.5 million and $9.4 million, respectively, and total equity was understated by $9.4 million for the three months ended March 31, 2010. Accordingly, we are now restating our unaudited condensed consolidated financial statements as of and for the three months ended March 31, 2010 and related disclosure presented in the Form 10-Q to give effect to these adjustments to the commodity derivative assets and unrealized natural gas hedge gains. Please read Part I, Item 1. “Financial Statements, Note 16—Restatement of Previously Issued Financial Statements” to our condensed consolidated financial statements for further discussion of the restatement.

The restatement only affects, and this Amendment only revises, (i) certain information in Part I, Item 1, “Financial Statements—Condensed Consolidated Balance Sheets as of March 31, 2010 and December 31, 2009;” (ii) certain information in Part I, Item 1, “Financial Statements—Condensed Consolidated Statements of Operations for the Three Months Ended March 31, 2010 and 2009;” (iii) certain information in Part I, Item 1, “Financial Statements—Condensed Consolidated Statements of Cash Flows for the Three Months Ended March 31, 2010 and 2009;” (iv) certain information in Part I, Item 1, “Financial Statements—Notes to our Consolidated Financial Statements;” (v) certain information in Part I, Item 2, “Management’s Discussion and Analysis of Financial Condition and Results of Operations;” and (vi) certain information in Part I, Item 4, “Controls and Procedures.” In addition, as required by Rule 12b-15 under the Securities Exchange Act of 1934 (the “Exchange Act”), we are updating the exhibit table to add new certifications, as specified by Rules 13a-14(a)/15d-14(a) and 13a-14(b)/15d-14(b) of the Exchange Act, by our principal executive officer and principal financial officer to be filed or furnished, as indicated, as exhibits to this Amendment under Part II, Item 6, “Exhibits” hereof.

This Amendment speaks as of the date of the Form 10-Q. We have not updated the information in the Form 10-Q, including the information set forth in the sections referenced above, except as necessary to reflect the effects of the restatement described above. This Amendment does not reflect events occurring after the filing of the Form 10-Q and any information included herein that was not affected by the restatement remains unchanged and reflects the disclosures made at the time of filing the Form 10-Q on May 6, 2010. As a result, this Form 10-Q, as amended hereby, contains forward-looking information that has not been updated for events subsequent to the date of the original filing of the Form 10-Q. Accordingly, this Form 10-Q, as amended hereby, should be read in conjunction with our subsequent filings with the SEC, as information in such filings may update or supersede certain information contained in this Amendment. The filing of this Amendment shall not be deemed an admission that the Form 10-Q, when made, included any untrue statement of material fact or omitted to state a material fact necessary to make a statement not misleading.

GASTAR EXPLORATION LTD.

QUARTERLY REPORT ON FORM 10-Q/A

FOR THE THREE MONTHS ENDED MARCH 31, 2010

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		Page
	PART I—FINANCIAL INFORMATION

Item 1.	Financial Statements	2
	Condensed Consolidated Balance Sheets as of March 31, 2010 and December 31, 2009	2
	Condensed Consolidated Statements of Operations for the Three Months Ended March 31, 2010 and 2009	3
	Condensed Consolidated Statements of Cash Flows for the Three Months Ended March 31, 2010 and 2009	4
	Notes to the Condensed Consolidated Financial Statements	5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	24
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	31
Item 4.	Controls and Procedures	31

	PART II—OTHER INFORMATION

Item 1.	Legal Proceedings	32
Item 1A.	Risk Factors	32
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	33
Item 3.	Defaults Upon Senior Securities	33
Item 4.	(Removed and Reserved)	33
Item 5.	Other Information	33
Item 6.	Exhibits	33
SIGNATURES		34

Unless otherwise indicated or required by the context, (i) “Gastar,” the “Company,” “we,” “us,” and “our” refer to Gastar Exploration Ltd. and its subsidiaries and predecessors, (ii) all dollar amounts appearing in this Form 10-Q, as amended hereby, are stated in United States dollars (“US dollars”) and (iii) all financial data included in this Form 10-Q, as amended hereby, have been prepared in accordance with generally accepted accounting principles in the United States of America (“US GAAP”).

General information about us can be found on our website at www.gastar.com. The information on our website is neither incorporated into, nor part of, the Form 10-Q, as amended hereby. Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q and Current Reports on Form 8-K, as well as any amendments and exhibits to those reports, will be available free of charge through our website as soon as reasonably practicable after we file or furnish them to the SEC. Information is also available on the SEC website at www.sec.gov for our United States filings and on SEDAR at www.sedar.com for our Canadian filings. As of the opening of trading on August 3, 2009, a common share consolidation on the basis of one (1) common share for five (5) common shares (the “1-for-5 Reverse Split”) became effective. All common share and per share amounts reported in the Form 10-Q, as amended hereby, have been reported on a post reverse split basis.

PART I. FINANCIAL INFORMATION

Item 1.

Financial Statements

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS


	March 31, 2010			December 31, 2009
	(Unaudited) (Restated - See Note 16)
	(in thousands)
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	11,737		$	21,866
Term deposit		76,576			69,662
Accounts receivable, net of allowance for doubtful accounts of $600 and $609, respectively		5,508			5,336
Receivable from unproved property sale		1,839			19,412
Receivables from commodity derivative contracts		10,417			4,870
Prepaid expenses		598			669

Total current assets		106,675			121,815

PROPERTY, PLANT AND EQUIPMENT:
Natural gas and oil properties, full cost method of accounting:
Unproved properties, excluded from amortization		143,965			132,720
Proved properties		314,979			313,100

Total natural gas and oil properties		458,944			445,820
Furniture and equipment		933			867

Total property, plant and equipment		459,877			446,687
Accumulated depreciation, depletion and amortization		(285,757	)		(284,026	)

Total property, plant and equipment, net		174,120			162,661

OTHER ASSETS:
Restricted cash		50			50
Receivables from commodity derivative contracts		12,012			10,698
Deferred charges, net		668			764
Drilling advances and other assets		100			250

Total other assets		12,830			11,762

TOTAL ASSETS	$	293,625		$	296,238

LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	10,700		$	8,291
Revenue payable		4,605			4,621
Accrued interest		58			130
Accrued drilling and operating costs		1,296			736
Liabilities from commodity derivative contracts		3,829			3,678
Commodity derivative premium payable		1,918			1,190
Short-term loan		—			17,000
Accrued taxes payable		77,146			75,887
Other accrued liabilities		1,979			1,438

Total current liabilities		101,531			112,971

LONG-TERM LIABILITIES:
Warrant derivative		57			205
Liabilities from commodity derivative contracts		3,532			4,047
Commodity derivative premium payable		7,448			8,176
Asset retirement obligation		6,049			5,943

Total long-term liabilities		17,086			18,371

Commitments and contingencies (Note 13)

SHAREHOLDERS’ EQUITY:
Preferred stock, no par value; unlimited shares authorized; no shares issued		—			—
Common stock, no par value; unlimited shares authorized; 50,399,695 and 50,028,592 shares issued and outstanding at March 31, 2010 and December 31, 2009, respectively		263,809			263,809
Additional paid-in capital		21,501			20,782
Accumulated deficit		(110,302	)		(119,695	)

Total shareholders’ equity		175,008			164,896

TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	293,625		$	296,238

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

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)


	For the Three Months Ended March 31,
	2010 (Restated - See Note 16)			2009
	(in thousands, except share and per share data)
REVENUES:
Natural gas and oil revenues	$	6,758		$	13,461
Unrealized natural gas hedge gain (loss)		9,378			(196	)

Total revenues		16,136			13,265

EXPENSES:
Production taxes		123			157
Lease operating expenses		1,743			1,877
Transportation, treating and gathering		1,249			493
Depreciation, depletion and amortization		1,731			7,999
Impairment of natural gas and oil properties		—			68,729
Accretion of asset retirement obligation		95			87
General and administrative expense		3,832			2,958

Total expenses		8,773			82,300

INCOME (LOSS) FROM OPERATIONS		7,363			(69,035	)

OTHER INCOME (EXPENSE):
Interest expense		(78	)		(1,162	)
Investment income and other		792			13
Warrant derivative gain		148			—
Foreign transaction gain (loss)		319			(3	)

INCOME (LOSS) BEFORE PROVISION FOR INCOME TAXES		8,544			(70,187	)
Provision for income taxes		(849	)		—

NET INCOME (LOSS)	$	9,393		$	(70,187	)

NET INCOME (LOSS) PER SHARE:
Basic	$	0.19		$	(1.69	)

Diluted	$	0.19		$	(1.69	)

WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
Basic		48,997,016			41,452,423
Diluted		49,486,656			41,452,423

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

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Three Months Ended March 31,
	2010 (Restated - See Note 16)			2009
	(in thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$	9,393		$	(70,187	)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization		1,731			7,999
Impairment of natural gas and oil properties		—			68,729
Stock-based compensation		759			1,421
Unrealized natural gas hedge (gain) loss		(9,378	)		196
Realized loss (gain) on derivative contracts		1,039			(1,280	)
Amortization of deferred financing costs and debt discount		96			686
Accretion of asset retirement obligation		95			87
Warrant derivative gain		(148	)		—

Changes in operating assets and liabilities:
Accounts receivable		1,451			3,591
Commodity derivative contracts		1,114			2,889
Prepaid expenses		71			81
Accrued taxes payable		1,259			—
Accounts payable and accrued liabilities		(112	)		(942	)

Net cash provided by operating activities		7,370			13,270

CASH FLOWS FROM INVESTING ACTIVITIES:
Development and purchase of natural gas and oil properties		(10,830	)		(21,450	)
Proceeds from sale of natural gas and oil properties		17,350			—
Purchase of furniture and equipment		(66	)		(7	)
Purchase of term deposit		(6,914	)		—

Net cash used in investing activities		(460	)		(21,457	)

CASH FLOWS FROM FINANCING ACTIVITIES:
Repayment of revolving credit facility		—			(2,000	)
Repayment of short-term loan		(17,000	)		—
Proceeds from term loan		—			25,000
Increase in restricted cash		—			(465	)
Deferred financing charges		—			(1,430	)
Other		(39	)		(208	)

Net cash (used in) provided by financing activities		(17,039	)		20,897

NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS		(10,129	)		12,710
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD		21,866			6,153

CASH AND CASH EQUIVALENTS, END OF PERIOD	$	11,737		$	18,863

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

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. Description of Business

Gastar Exploration Ltd. (“Gastar”, the “Company” or “Parent”) is an independent energy company engaged in the exploration, development and production of natural gas and oil in the United States. The Company’s principal business activities include the identification, acquisition, and subsequent exploration and development of natural gas and oil properties with an emphasis on prospective deep structures identified through seismic and other analytical techniques as well as unconventional natural gas reserves, such as shale resource plays. The Company currently is pursuing natural gas exploration in the deep Bossier gas play in the Hilltop area of East Texas and the Marcellus Shale play in the Appalachian area of West Virginia and central and southwestern Pennsylvania. The Company also conducts coal bed methane (“CBM”) development activities within the Powder River Basin of Wyoming and Montana.

2. Summary of Significant Accounting Policies

The accounting policies followed by the Company and its subsidiaries are set forth in the notes to the Company’s audited consolidated financial statements included in its Annual Report on Form 10-K for the year ended December 31, 2009 (“2009 Form 10-K”) filed with the SEC. Please refer to the notes to the financial statements included in the Company’s 2009 Form 10-K for additional details of the Company’s financial condition, results of operations and cash flows. All material items included in those notes have not changed except as a result of normal transactions in the interim or as disclosed within this report.

The unaudited interim condensed consolidated financial statements of the Company included herein are stated in US dollars unless otherwise noted and were prepared from the records of the Company by management in accordance with US GAAP applicable to interim financial statements and reflect all normal and recurring adjustments, which are, in the opinion of management, necessary to provide a fair presentation of the results of operations and financial position for the interim periods. Such financial statements conform to the presentation reflected in the Company’s 2009 Form 10-K. The current interim period reported herein should be read in conjunction with the financial statements and accompanying notes, including Item 8. “Financial Statements and Supplementary Data, Note 2—Summary of Significant Accounting Policies” included in the Company’s 2009 Form 10-K. The year-end condensed balance sheet data was derived from audited financial statements but does not include all disclosures required by US GAAP.

The preparation of financial statements in conformity with US GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates with regard to these financial statements include the estimate of proved natural gas and oil reserve quantities and the related present value of estimated future net cash flows.

The condensed consolidated financial statements include the accounts of the Company and the consolidated accounts of all of its subsidiaries. The entities included in these consolidated accounts are wholly owned by the Company. All significant intercompany accounts and transactions have been eliminated in consolidation.

Certain reclassifications of prior year balances have been made to conform them to the current year presentation. These reclassifications have no impact on net income (loss).

The results of operations for the three months ended March 31, 2010 are not necessarily indicative of the results that may be expected for the year ending December 31, 2010.

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

In preparing these financial statements, the Company has evaluated events and transactions for potential recognition or disclosure through the date the financial statements were issued and has disclosed certain subsequent events in these condensed consolidated financial statements, as appropriate.

Recent Accounting Developments

The following recently issued accounting pronouncements have been adopted or may impact the Company in future periods:

Stock Compensation—Effect of Denominating the Exercise Price of a Share-Based Payment Award in the Currency of the Market in Which the Underlying Equity Security Trades. In April 2010, the Financial Accounting Standards Board (“FASB”)’s Emerging Issues Task Force (“EITF”) issued an amendment to previously issued guidance regarding the classification of a share-based payment award as either equity or a liability. The amendments clarify that a share-based payment award with an exercise price denominated in the currency of a market in which a substantial portion of the entity’s equity securities trades should not be considered to contain a condition that is not a market, performance or service condition. Therefore, such an award should not be classified as a liability if it otherwise qualifies as equity. This guidance is effective for fiscal years and interim periods within those fiscal years beginning on or after December 15, 2010. Earlier application is permitted. This guidance should be applied by recording a cumulative-effect adjustment to the opening balance of retained earnings and the cumulative-effect adjustment should be calculated for all awards outstanding as of the beginning of the fiscal year in which it is initially applied, as if the guidance had been applied consistently since the inception of the award. The cumulative-effect adjustment should be presented separately. The Company is currently evaluating the impact of this guidance on its operating results, financial position and cash flows.

Derivatives and Hedging. In March 2010, the FASB issued an amendment to previously issued guidance regarding embedded credit derivatives. This amendment provides clarification of the scope exception for embedded credit derivatives that transfer credit risk only in the form of subordination of one financial instrument to another. All entities that enter into contracts containing an embedded credit derivative feature related to the transfer of credit risk that is not only in the form of subordination of one financial instrument to another will be affected by the amendment because the amendment clarifies that the embedded credit derivative scope exception per the guidance does not apply to such contracts. This amended guidance is effective at the beginning of the first fiscal quarter beginning after June 15, 2010. Early adoption is permitted at the beginning of the first fiscal quarter beginning after the issuance of this amendment. The Company is currently evaluating the impact of this guidance on its operating results, financial position and cash flows.

Fair Value Measurements. In January 2010, the FASB issued authoritative guidance related to improving disclosures about fair value measurements. This guidance requires separate disclosures of the amounts of transfers in and out of Level 1 and Level 2 fair value measurements and a description of the reason for such transfers. In the reconciliation for Level 3 fair value measurements using significant unobservable inputs, information about purchases, sales, issuances and settlements shall be presented separately. These disclosures are required for interim and annual reporting periods effective January 1, 2010, except for the disclosures related to the purchases, sales, issuances and settlements in the roll forward activity of Level 3 fair value measurements, which are effective on January 1, 2011. This guidance was adopted on January 1, 2010 for Level 1 and Level 2 fair value measurements and did not impact the Company’s operating results, financial position or cash flows but did require additional disclosures regarding the fair value of financial instruments. See Item 1. “Financial Statements, Note 6—Fair Value Measurements.”

Variable Interest Entities. In June 2009, the FASB issued authoritative guidance related to variable interest entities which changes how a reporting entity determines when an entity that is insufficiently capitalized or is not controlled through voting rights should be consolidated and modifies the approach for determining the primary beneficiary of a variable interest entity. This guidance requires a reporting entity to provide additional disclosures about its involvement with variable interest entities and any significant changes in risk exposure due to that

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

involvement. The guidance related to variable interest entities was effective on January 1, 2010 and did not have an impact on the Company’s operating results, financial position or cash flows.

Subsequent Events. In May 2009, the FASB issued authoritative guidance on subsequent events to incorporate accounting guidance that originated as auditing standards into the body of authoritative literature issued by the FASB. This guidance required the evaluation of subsequent events through the date the financial statements are issued or are available for issue and the disclosure of the date through which subsequent events were evaluated and the basis for that date. This guidance was effective for interim and annual financial periods ending after June 15, 2009. The Company adopted the requirements of this guidance for the period ended June 30, 2009 and the adoption did not have an impact on the Company’s operating results, financial position or cash flows. On February 25, 2010, the FASB amended this guidance to remove the requirement to disclose the date through which an entity has evaluated subsequent events.

Modernization of Natural Gas and Oil Reporting. In January 2009, the SEC issued revisions to the natural gas and oil reporting disclosures, “Modernization of Oil and Gas Reporting, Final Rule” (the “Final Rule”). In addition to changing the definition and disclosure requirements for natural gas and oil reserves, the Final Rule changed the requirements for determining quantities of natural gas and oil reserves. The Final Rule also changed certain accounting requirements under the full cost method of accounting for natural gas and oil activities. The amendments are designed to modernize the requirements for the determination of natural gas and oil reserves, aligning them with current practices and updating them for changes in technology. The Final Rule was effective for annual reports on Form10-K for fiscal years ending on or after December 31, 2009. In addition, in January 2010, the FASB issued an accounting standards update relating to standards for extractive oil and gas activities. The accounting standards update amends existing standards to align the proved reserves calculation and disclosure requirements under US GAAP with the requirements in the SEC rules. The Company adopted the new standards effective December 31, 2009. The new standards were applied prospectively as a change in estimate. The use of the Final Rule’s historical 12-month unweighted average of the first-day-of-the-month price affected the Company’s depletion expense calculation for the first quarter of 2010 resulting in an decreased expense of approximately $16,000 and did not have an impact on earnings per share. In April 2010, the FASB issued a further accounting standards update regarding extractive oil and gas industries to incorporate in accounting standards the revisions to Rule 4-10 of the SEC’s Regulation S-X. The amendment primarily consists of the addition and deletion of definitions of terms related to fossil fuel exploration and production arising from technology changes over the past several decades. The accounting guidance in Rule 4-10 did not change.

3. Property, Plant and Equipment

The amount capitalized as natural gas and oil properties was incurred for the purchase and development of various properties in the United States (“US”), specifically the states of Montana, Pennsylvania, Texas, West Virginia and Wyoming.

At March 31, 2010, unproved properties excluded from amortization consisted of drilling in progress costs of $7.3 million, acreage acquisition costs of $118.7 million and capitalized interest of $18.0 million. At December 31, 2009, unproved properties excluded from amortization consisted of drilling in progress costs of $3.8 million, acreage acquisition costs of $111.0 million and capitalized interest of $17.9 million. The Company’s East Texas exploration is ongoing and currently is anticipated to be completed over the next six years. The Marcellus Shale exploration activities have commenced, and the Company currently anticipates these activities could continue for up to 10 years.

Management’s ceiling test evaluation for the three months ended March 31, 2010 did not result in an impairment of proved properties. The March 31, 2010 ceiling test evaluation utilized a historical 12-month unweighted average of the first-day-of-the-month Henry Hub natural gas price of $3.99 per MMBtu. For the three months ended March 31, 2009, the results of management’s ceiling test evaluation resulted in an impairment of proved properties of $68.7 million. The March 31, 2009 ceiling test evaluation utilized a period-end Henry Hub natural gas price of $3.61 per MMBtu.

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

Sale of Petroleum Exploration Licenses 238, 433, and 434 and Repayment of Debt

On July 13, 2009, Gastar Exploration New South Wales, Inc. (“Gastar New South Wales”) and Gastar Exploration USA, Inc. (“Gastar USA”), each wholly owned subsidiaries of the Company, completed the sale of all of the Company’s interest in Petroleum Exploration Licenses (“PEL”) 238 (including Petroleum Production License 3), PEL 433, and PEL 434 in New South Wales, Australia and the concurrent sale of the Company’s common shares of Gastar Power Pty Ltd. (“Gastar Power”), the Company’s wholly-owned subsidiary holding its 35% working interest in the Wilga Park Power Station (collectively, the “Australian Assets”), to Santos QNT Pty Ltd. and Santos International Holdings Pty Ltd. (collectively, “Santos”). The sale was made pursuant to a definitive sale agreement dated July 2, 2009 by and among Gastar New South Wales, Gastar USA and Santos.

The Australian Assets included the Company’s 35% working interest in PEL 238, a CBM exploratory property covering approximately 2.2 million gross (761,400 net) acres, located in the Gunnedah Basin of New South Wales, as well as 1.9 million gross (664,000 net) acres in PEL 433, approximately 1.9 million gross (669,000 net) acres in PEL 434 and the Company’s foreign subsidiary, Gastar Power, which acquired a 35% working interest in the Wilga Park Power Station in February 2009.

Including gross reserve certification target proceeds, the Australian Assets were sold for an aggregate purchase price of $250.4 million (AU$320.0 million), before transaction costs of $1.5 million, resulting in a gain on the sale of assets of $211.2 million at December 31, 2009. At March 31, 2010, the Company had received approximately $248.9 million (AU$318.0 million), excluding taxes and transaction expenses, with the balance to be paid upon receipt of certain government approvals. In April 2010, the final governmental approval was obtained and Santos remitted the remaining balance based on the current foreign exchange rate of approximately $1.8 million (AU$2.0 million) to the Company. The sale agreement also acknowledged the Company’s retention of its right to future cash payments of up to $10.0 million pursuant to a pre-existing farm-in agreement in the event certain production thresholds are reached on PEL 238. The Company follows the full cost method of accounting, which typically does not allow for gain on sale recognition involving less than 25% of the reserves in a given cost center. All of the Company’s properties in Australia were sold to Santos; therefore, gain recognition on the sale of unproven property was deemed the proper accounting treatment.

The Company used the proceeds from the sale of the Australian Assets to (i) repay the $13.0 million outstanding on its secured Original Revolving Credit Facility, (ii) repay in full its $25.0 Million Term Loan, (iii) repurchase all of its outstanding $100.0 million 12³/4% Senior Secured Notes due December 31, 2012 at a price of 106.375% of par, plus accrued and unpaid interest, (iv) repay, at par, an initial $10.3 million of its Convertible Subordinated Debentures, and (v) repay the remaining $300,000 of Subordinated Unsecured Notes Payable.

4. Short-Term Loan

On November 20, 2009, the Parent entered into a $17.0 million secured short-term loan agreement with the lender parties and administrative agent thereto (the “Short-Term Loan”). Concurrent with the execution of the Short-Term Loan, the Parent drew $17.0 million and used the proceeds, together with cash on hand, to repay all $19.7 million of its outstanding 9.75% convertible senior unsecured subordinated debentures due November 20, 2009. The Short-Term Loan bore interest at the floating prime rate of the lender, or 5.0% per annum, from issuance to repayment. The Short-Term Loan was repaid in full on January 8, 2010.

5. Long-Term Debt

Revolving Credit Facility

On October 28, 2009, Gastar USA, together with the Parent and Subsidiary Guarantors, and the lenders, administrative agent and letter of credit issuer party thereto, entered into an amended and restated credit facility, amending and restating in its entirety the original revolving credit facility (the “Revolving Credit Facility”). The Revolving Credit Facility provided an initial borrowing base of $47.5 million, with borrowings bearing interest, at

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

the Company’s election, at the prime rate or LIBO rate plus an applicable margin. Pursuant to the Revolving Credit Facility, the applicable interest rate margin varies from 1.0% to 2.0% in the case of borrowings based on the prime rate and from 2.5% to 3.5% in the case of borrowings based on LIBO rate, depending on the utilization percentage in relation to the borrowing base. An annual commitment fee of 0.50% is payable quarterly based on the unutilized balance of the borrowing base. The Revolving Credit Facility has a scheduled maturity date of January 2, 2013.

The Revolving Credit Facility is guaranteed by the Parent and all its current domestic subsidiaries and all future domestic subsidiaries formed during the term of the Revolving Credit Facility. Borrowings and related guarantees under the Revolving Credit Facility are secured by a first priority lien on all domestic natural gas and oil properties currently owned by or later acquired by Gastar USA and its subsidiaries, excluding de minimus value properties as determined by the lender. The facility is secured by a first priority pledge of the stock of each domestic subsidiary, a first priority interest on all accounts receivable, notes receivable, inventory, contract rights, general intangibles and material property of the issuer and 65% of the stock of each foreign subsidiary of Gastar USA.

The Revolving Credit Facility contains various covenants, including among others:

•

Restrictions on liens;

•

Restrictions on incurring other indebtedness without the lenders’ consent;

•

Restrictions on dividends and other restricted payments;

•

Maintenance of a minimum consolidated current ratio as of the end of each quarter of not less than 1.0 to 1.0, as adjusted;

•

Maintenance of a maximum ratio of indebtedness to EBITDA on a rolling four quarter basis, as adjusted, of not greater than 4.0 to 1.0, commencing with the quarter ended December 31, 2009; and

•

Maintenance of an interest coverage ratio on a rolling four quarters basis, as adjusted, of EBITDA to interest expense, as of the end of each quarter commencing December 31, 2009, to be less than 2.5 to 1.0.

All outstanding amounts owed under the Revolving Credit Facility become due and payable upon the occurrence of certain usual and customary events of default, including among others:

•

Failure to make payments under the Revolving Credit Facility;

•

Non-performance of covenants and obligations continuing beyond any applicable grace period; and

•

The occurrence of a “Change in Control” (as defined in the Revolving Credit Facility) of the Parent.

Should there occur a Change in Control of the Parent, then, five days after such occurrence, immediately and without notice, (i) all amounts outstanding under the Revolving Credit Facility shall automatically become immediately due and payable and (ii) the commitments shall immediately cease and terminate unless and until reinstated by the lender in writing. If amounts outstanding under the Revolving Credit Facility become immediately due and payable, the obligation of Gastar USA with respect to any commodity hedge exposure shall be to provide cash as collateral to be held and administered by the lender as collateral agent.

Credit support for the Company’s open derivatives at March 31, 2010 is provided through inter-creditor agreements or by a $100,000 letter of credit. As of March 31, 2010, after reflecting this letter of credit, the remaining availability under the borrowing base available to the Company was $47.4 million. During April 2010, the $100,000 letter of credit was cancelled. The borrowing base currently available to the Company is $47.5 million but is subject to change based on the results of the current redetermination which is scheduled to be completed during the second quarter of 2010.

At March 31, 2010, the Company was in compliance with all financial covenants under the Revolving Credit Facility.

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

6. Fair Value Measurements

The information set forth in this Note is restated herein. Please read Note 16 “Restatement of Previously Issued Financial Statements” for further discussion of the restatement.

The Company’s financial assets and liabilities are measured at fair value on a recurring basis. The Company discloses its recognized non-financial assets and liabilities, such as asset retirement obligations and other property and equipment, at fair value on a non-recurring basis. For non-financial assets and liabilities, the Company is required to disclose information that enables users of its financial statements to assess the inputs used to develop these measurements. As none of the Company’s non-financial assets and liabilities were impaired during the period-ended March 31, 2010, and no other fair value measurements are required to be recognized on a non-recurring basis, no additional disclosures are provided at March 31, 2010.

As defined in the guidance, fair value is the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (“exit price”). To estimate fair value, the Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. The guidance establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted market prices in active markets for identical assets or liabilities (“Level 1”) and the lowest priority to unobservable inputs (“Level 3”). The three levels of the fair value hierarchy are as follows:

–

Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities. The Company’s cash equivalents consist of short-term, highly liquid investments, which have maturities of 90 days or less, including sweep investments and money market funds.

–

Level 2 inputs are quoted prices for similar assets and liabilities in active markets or inputs that are observable for the asset or liability, either directly or indirectly through market corroboration, for substantially the full term of the financial instrument.

–

Level 3 inputs are measured based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable from objective sources. These inputs may be used with internally developed methodologies or third party broker quotes that result in management’s best estimate of fair value. The Company’s valuation models consider various inputs including (a) quoted forward prices for commodities, (b) time value, (c) volatility factors and (d) current market and contractual prices for the underlying instruments. Level 3 instruments are natural gas costless collars, warrants, index, basis and fixed price swaps and put and call options. At each balance sheet date, the Company performs an analysis of all applicable instruments and includes in Level 3 all of those whose fair value is based on significant unobservable inputs.

As required, financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The determination of the fair values below incorporates various factors, including the impact of the counterparty’s non-performance risk with respect to the Company’s financial assets and the Company’s non-performance risk with respect to the Company’s financial liabilities. The Company has not elected to offset the fair value amounts recognized for multiple derivative instruments executed with the same counterparty, but report them gross on its condensed consolidated balance sheets.

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

The following table sets forth by level within the fair value hierarchy the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis as of March 31, 2010:


	Fair value as of March 31, 2010
	(Restated - See Note 16)
	Level 1		Level 2		Level 3			Total
	(in thousands)
Assets:
Cash and cash equivalents	$	11,737	$	—	$	—		$	11,737
Commodity derivative contracts		—		—		22,429			22,429
Liabilites:
Commodity derivative contracts		—		—		(7,361	)		(7,361	)
Warrant derivative		—		—		(57	)		(57	)

Total	$	11,737	$	—	$	15,011		$	26,748

The table below presents a reconciliation of the assets and liabilities classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2010. Level 3 instruments presented in the table consist of net derivatives that, in management’s judgment, reflect the assumptions a marketplace participant would have used at March 31, 2010.


	Derivatives for the Three Months Ended March 31, 2010
	(Restated - See Note 16)
	(in thousands)
Balance at January 1, 2010	$	7,638
Total gains (losses) (realized or unrealized):
included in earnings		8,528
included in other comprehensive income		—
Purchases		—
Issuances		—
Settlements (1)		(1,155	)
Transfers in and (out) of Level 3		—

Balance at March 31, 2010	$	15,011

The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at March 31, 2010	$	9,526

(1)	During the three months ended March 31, 2010, the Company sold calls at a weighted average price of $6.92 on approximately 3.3 MMBtu per day for the period April 2010 through December 2012 yielding $1.1 million of cash settlements.

At March 31, 2010, the estimated fair value of cash and cash equivalents, term deposits, accounts receivable and accounts payable approximates their carrying value due to their short-term nature.

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

The fair value guidance, as amended, establishes that every derivative instrument is to be recorded on the balance sheet as either an asset or liability measured at fair value. See Item 1. “Financial Statements, Note 7—Derivative Instruments and Hedging Activity.”

7. Derivative Instruments and Hedging Activity

The information set forth in this Note is restated herein. Please read Note 16 “Restatement of Previously Issued Financial Statements” for further discussion of the restatement.

The Company maintains a commodity price risk management strategy that uses derivative instruments to minimize significant, unanticipated earnings fluctuations that may arise from volatility in commodity prices. The Company uses costless collars, index, basis and fixed price swaps and put and call options to hedge natural gas price risk.

Effective October 1, 2008, the Company elected to discontinue hedge accounting on all existing derivative contracts and elected not to designate any derivative contracts as cash flow hedges. Any hedge effectiveness related to the Company’s previous cash flow hedging relationships were to remain in other comprehensive income until the underlying forecasted transactions affected earnings. As a result, for the three months ended March 31, 2009, the Company reported gains of $856,000, which were reclassified into earnings as a result of previously discontinued cash flow hedges. As of December 31, 2009, all other comprehensive income had been reclassified to earnings. All derivative contracts are carried at their fair value on the balance sheet and all unrealized gains and losses are recorded in the statement of operations in unrealized natural gas hedge gain (loss), while realized gains and losses related to contract settlements are recognized in natural gas and oil revenues. For the three months ended March 31, 2010 and 2009, the Company reported unrealized gains of $9.4 million and unrealized losses of $196,000, respectively, in the statement of operations related to the change in the fair value of its commodity derivative instruments.

As of March 31, 2010, the following derivative transactions were outstanding with the associated notational volumes and weighted average underlying hedge prices:


Settlement Period	Derivative Instrument	Average Daily Volume	Total of Notional Volume	Base Fixed Price			Floor (Long)		Short Put		Ceiling (Short)
		(in MMBtu’s)
2010	Put spread	19,984	2,378,000		$ —		$	6.02	$	4.13	$	—
2010	Costless collar	14,762	2,554,500		—			5.96		4.51		7.90
2010	Basis—HSC (1)	14,722	3,895,000		(0.24	)		—		—		—
2010	Basis—CIG (2)	1,000	275,000		(1.31	)		—		—		—
2011	Put spread	2,673	981,550		—			6.00		4.00		—
2011	Costless collar	15,320	4,903,450		—			6.12		4.22		7.74
2011	Fixed price swap	2,000	730,000		6.11			—		—		—
2011	Basis—HSC (1)	800	292,000		(1.21	)		—		—		—
2011	Basis—CIG (2)	10,167	1,839,000		(0.23	)		—		—		—
2012	Put spread	13,028	4,770,420		—			6.00		4.00		—
2012	Costless collar	5,410	1,979,580		—			6.00		4.00		7.39

(1)	East Houston-Katy—Houston Ship Channel

(2)	Inside FERC Colorado Interstate Gas, Rocky Mountains

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

As of March 31, 2010, all of the Company’s economic derivative hedge positions were with a multinational energy company or large financial institution, which are not known to the Company to be in default on their derivative positions. Credit support for the Company’s open derivatives at March 31, 2010 is provided under the Revolving Credit Facility through inter-creditor agreements or under a $100,000 letter of credit. The Company is exposed to credit risk to the extent of non-performance by the counterparties in the derivative contracts discussed above; however, the Company does not anticipate non-performance by such counterparties. None of the Company’s derivative instruments contains credit-risk related contingent features.

In conjunction with certain derivative hedging activity, the Company deferred the payment of certain put premiums for the production month period July 2010 through December 2012. At March 31, 2010, the Company had a current commodity derivative premium payable of $1.9 million and a long-term commodity derivative premium payable of $7.4 million. The put premium liabilities become payable monthly as the hedge production month becomes the prompt production month.

Warrants

The Company reclassified the fair value of its warrants to purchase common stock, which had exercise price reset features, from equity to liability status as if these warrants were treated as a derivative liability since their date of issue in June 2008. On January 1, 2009, the Company reclassified from additional paid-in capital, as a cumulative effect adjustment, $5.4 million to beginning retained earnings and did not recognize any value to common stock warrant liability for representing the fair value of such warrants on such date. The fair value of these warrants to purchase common stock was $57,000 as of March 31, 2010, and the Company recognized a $148,000 unrealized gain in other income for the change in fair value of these warrants for the three months ended March 31, 2010.

The following warrants to purchase common shares were outstanding as of March 31, 2010:

Warrants

Outstanding

Fair Value
(in thousands)

Weighted
Price per
Share Range

Weighted
Average
Remaining
Life in
Years

Average
Exercise
Price

2,000,000

(1)

1.7

(1)

The warrants are exercisable for $13.75 per share in the event that, on or before June 11, 2011, the Company sells all or substantially all of its present natural gas and oil interests located in Leon and Robertson Counties in East Texas for net proceeds exceeding $500.0 million. A sale or a series of sales of all or substantially all of the Company’s present East Texas properties prior to June 11, 2011 for $500.0 million or less will terminate the warrants. If the Company does not sell all or substantially all of these properties by June 11, 2011, the warrants will be exercisable for a six-month period commencing on that date at $15.00 per share. The Company is not obligated to sell any of its East Texas properties. Fair value is based on the Black-Scholes-Merton model for option pricing.

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

Additional Disclosures about Derivative Instruments and Hedging Activities

The tables below provide information on the location and amounts of derivative fair values in the statement of financial position and derivative gains and losses in the statement of operations for derivative instruments that are not designated as hedging instruments:


	Fair Values of Derivative Instruments Derivative Assets (Liabilities)
	Balance Sheet Location	Fair Value
	Balance Sheet Location	March 31, 2010 (Restated - See Note 16)			December 31, 2009
		(in thousands)
Derivatives not designated as hedging instruments
Current	Receivables from commodity derivative contracts	$	10,417		$	4,870
Long-term	Receivables from commodity derivative contracts		12,012			10,698
Current	Liabilities from commodity derivative contracts		(3,829	)		(3,678	)
Long-term	Liabilities from commodity derivative contracts		(3,532	)		(4,047	)
Long-term	Warrant derivative		(57	)		(205	)

Total derivatives not designated as hedging instruments		$	15,011		$	7,638


	Amount of Gain (Loss) Recognized in Income on Derivatives
	Location of Gain (Loss) Recognized in Income on Derivatives	Amount of Gain (Loss) Recognized in Income on Derivatives For the Three Months Ended
		March 31, 2010 (Restated - See Note 16)			March 31, 2009
		(in thousands)
Derivatives not designated as hedging instruments
Commodity derivative contracts	Unrealized natural gas hedge gain (loss)	$	9,378		$	(196	)
Warrant derivative	Other income (expense)		148			—

Total		$	9,526		$	(196	)

8. Capital Stock

Common Shares

The Company’s articles of incorporation allow the Company to issue an unlimited number of common shares without par value. On July 23, 2009, the Company filed an article of amendment to its articles of incorporation with the Registrar of Corporations of Alberta, Canada for the purpose of affecting the 1-for-5 Reverse Split. The Company’s shareholders approved the reverse split at the 2008 Annual General and Special Meeting of Shareholders held on June 20, 2008 by a special resolution authorizing a reverse split of the Company’s common shares on the basis of one (1) new common share for up to five (5) common shares outstanding or such fewer number of common shares as the Board of Directors may, in its sole discretion, approve at a later date. The Board of Directors approved the 1-for-5 Reverse Split on June 29, 2009. As of the opening of trading on August 3, 2009, the Company’s common shares began trading on the NYSE Amex under the same symbol of “GST” on a post 1-for-5 Reverse Split basis. No scrip or fractional certificates were issued in connection with the 1-for-5 Reverse Split. Shareholders who otherwise would have been entitled to receive fractional shares because they held a number of common shares not evenly divisible by five received a number of shares after rounding up to the next common share. All common share and per share amounts reported in the Form 10-Q, as amended herby, have been reported on a post 1-for-5 Reverse Split basis.

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

Preferred Shares

On June 30, 2009, the Company filed an amendment to its articles of incorporation to be effective as of June 30, 2009 with the Registrar of Corporations of Alberta, Canada for the purpose of creating and adding an unlimited number of preferred shares to the authorized capital of the Company. The Company’s shareholders approved the amendment by special resolution at the 2007 Annual General and Special Meeting of Shareholders held on June 1, 2007. Pursuant to the amendment, the number of preferred shares which may be issued from time to time and the privileges, restrictions and conditions of such preferred shares when issued will be determined by the Board of Directors of the Company.

Other Share Issuances

During the three months ended March 31, 2010 and pursuant to the Company’s 2006 Long-Term Incentive Plan, 379,050 common shares were granted and issued. In addition, 7,947 common shares were forfeited in connection with the payment of estimated withholding taxes on restricted shares that vested during the period.

Shares Reserved

At March 31, 2010, the Company has reserved 4,720,844 common shares to be issued pursuant to the exercise of stock options (1,332,300 common shares), the issuance of granted but unvested restricted shares (1,388,544 common shares) and the exercise of a warrant (2,000,000 common shares).

9. Interest Expense

The following table summarizes the components of interest expense for the periods indicated:


	For the Three Months Ended March 31,
	2010			2009
	(in thousands)
Interest expense:
Cash and accrued	$	105		$	4,826
Amortization of deferred financing costs and debt discount		96			686
Capitalized interest		(123	)		(4,350	)

Total interest expense	$	78		$	1,162

10. Related Party Transactions

Chesapeake Energy Corporation

On November 4, 2005, November 11, 2006 and May 23, 2007, Chesapeake Energy Corporation (“Chesapeake”) acquired 5,430,328, 1,000,000 and 351,439 common shares, respectively, in private placement transactions. Chesapeake has the right, with certain exceptions, to maintain its percentage ownership of the Company, on a fully diluted basis, by participating in future stock issuances and has the right to have an observer present at meetings of the Board of Directors.

As of March 31, 2010, Chesapeake owned 6,781,767 common shares, or 13.5% of the Company’s outstanding common shares. See Item 1. “Financial Statements, Note 13—Commitments and Contingencies.”

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

11. Income Taxes

For the three months ended March 31, 2010, the Company recognized a current tax benefit of $849,000 primarily as a result of the Australian Taxation Office’s (“ATO”) issuance of an amended assessment of the income tax with respect to the gain on sale of the Company’s Australian Assets in July 2009. The issuance of the amended assessment by the ATO represents a final resolution in favor of the Company of certain tax issues that could not be resolved until the ATO completed its review of the Australian Assets sale in April 2010. During the current quarter, the ATO resolution resulted in the recognition of an Australian tax expense benefit of AU$1.3 million ($1.0 million), which was reduced by AU$213,000 ($196,000) of Australian withholding tax on interest income earned on term deposits in Australia from the date of the sale through March 31, 2010.

12. Earnings per Share

The information set forth in this Note is restated herein. Please read Note 16 “Restatement of Previously Issued Financial Statements” for further discussion of the restatement.

In accordance with the provisions of authoritative guidance, basic earnings or loss per share is computed on the basis of the weighted average number of common shares outstanding for the period. Diluted earnings or loss per share is computed based upon the weighted average number of common shares plus the assumed issuance of common shares for all potentially dilutive securities. Potentially dilutive securities are not included in the computation of diluted loss per share, as such the effect would be anti-dilutive.


	For the Three Months Ended March 31,
	2010 (Restated - See Note 16)		2009
	(in thousands, except per share and share data)
Net income (loss)	$	9,393	$	(70,187	)
Weighted average common shares outstanding—basic		48,997,016		41,452,423
Incremental shares from unvested restricted shares		414,182		—
Incremental shares from outstanding stock options		75,458		—

Weighted average common shares outstanding—diluted		49,486,656		41,452,423

Income (loss) per common share:
Basic	$	0.19	$	(1.69	)
Diluted	$	0.19	$	(1.69	)

Common shares excluded from denominator as anti-dilutive:
Unvested restricted shares		—		620,430
Stock options		1,075,000		2,132,050
Warrants		2,000,000		2,046,504
Convertible subordinated debentures		—		1,369,863

Total		3,075,000		6,168,847

13. Commitments and Contingencies

Litigation

Navasota Resources L.P. (“Navasota”) vs. First Source Texas, Inc., First Source Gas L.P. (now Gastar Exploration Texas LP) and Gastar Exploration Ltd. (Cause No. 0-05-451) District Court of Leon County, Texas12th Judicial District. This lawsuit, dated October 31, 2005, contends that the Company breached Navasota’s preferential right to purchase 33.33% of the Company’s interest in certain natural gas and oil leases located in Leon and Robertson Counties and sold to Chesapeake Energy Corporation pursuant to a transaction closed November 4,

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

2005. The preferential right claimed is under an operating agreement dated July 7, 2000. The Company contends, among other things, that Navasota neither properly nor timely exercised any preferential right election it may have had with respect to the inter-dependent Chesapeake transaction. In July 2006, the District Court of Leon County, Texas issued a summary judgment in favor of the Company and Chesapeake. Navasota filed a Notice of Appeal to the Tenth Court of Appeals in Waco. Oral argument was heard on September 26, 2007 and the Court of Appeals issued its opinion on January 9, 2008 reversing the trial court’s rulings, rendering judgment in favor of Navasota on its claims for breach of contract and specific performance, and remanding the case for further proceedings on Navasota’s other counts, which include claims for suit to quiet title, trespass to try title, tortuous interference with contract, conversion, money had and received, and declaratory relief. The Company and Chesapeake filed a motion for rehearing on February 6, 2008, which was denied on March 18, 2008. The Company and Chesapeake filed a joint Petition for Review in the Texas Supreme Court on May 13, 2008. On August 28, 2008, the Texas Supreme Court requested briefing on the merits. On January 9, 2009, the Texas Supreme Court denied the Petition for Review. On January 26, 2009, the Company and Chesapeake jointly filed a motion for rehearing in the Texas Supreme Court on its denial of the Petition for Review. On April 24, 2009, the Texas Supreme Court denied the Petition for Review.

Pursuant to a provision in the November 4, 2005 Purchase and Sale and Exploration Development Agreement with Chesapeake, Chesapeake acknowledged the existence of the Navasota lawsuit and claims and further agreed that if Navasota were to prevail on its claims, that Chesapeake would convey the affected interests it purchased from the Company to Navasota upon receipt of the purchase price and/or other consideration paid by Navasota. Therefore, the Company believes that Navasota’s exercise of its rights of specific performance should impact only Chesapeake’s assigned leasehold interests. However, in December 2008, Chesapeake stated to the Company that if the Texas Supreme Court were not to reverse the decision of the Tenth Court of Appeals, Chesapeake would seek rescission of the 2005 transaction and restitution of consideration paid, indicating that Chesapeake might assert such rescission and restitution as to the November 4, 2005 Purchase and Sale and Exploration Development Agreement; a November 4, 2005 Exploration and Development Agreement; and a November 4, 2005 Common Share Purchase Agreement. In its December 2008 communication, Chesapeake did not identify particular sums as to which it might seek restitution, but amounts paid to the Company in connection with the 2005 transaction could be asserted to include the $76.0 million paid by Chesapeake for the purchase of 5.5 million common shares as part of the transaction in 2005 and/or other amounts. Chesapeake has amended its Answer to include cross-claims and counterclaims, including a claim for rescission.

On or about June 9, 2009, Navasota filed and served its Fourth Amended Petition, essentially re-pleading its previously-asserted claims against the Company and Chesapeake. Navasota has exercised its rights of specific performance, and Chesapeake assigned leases to Navasota in July 2009.

In addition, while the Navasota Resources litigation is pending, it is possible that expenditures incurred, or authorizations for proposed expenditures, for drilling activities on leases which include the disputed interest may remain unpaid or not be authorized by the non-operators asserting competing ownership rights, which could require the Company to either fund a disproportionate amount of drilling costs at its own risk or postpone its drilling program on affected leases. The Company intends to vigorously defend all claims asserted in the suit.

Craig S. Tillotson v. S. David Plummer 2nd, Spencer Plummer 3rd, Tony Ferguson, John Parrott, Thomas Robinson, GeoStar Corporation, First Source Wyoming, Inc. GeoStar Financial Services Corporation, Gastar Exploration Ltd., Zeus Investments, LLC and John Does 1-10 (Civil No. 080412334). This lawsuit was filed on July 7, 2008 in Utah state court by Craig S. Tillotson (“Tillotson”), in which he alleges that he was fraudulently induced to invest in a mare leasing program operated by Classic Star LLC, (“ClassicStar”) a subsidiary of GeoStar Corporation (“GeoStar”), on the basis of certain verbal representations, and to convert interests in that program into shares of a working interest in the Powder River Basin. Tillotson asserts causes of action against all defendants including common law fraud, fraudulent inducement, statutory securities fraud under Utah state law, civil conspiracy, and negligent misrepresentation, and asserts certain additional causes of action only against GeoStar, a GeoStar affiliate, and David and Spencer Plummer. The Company has not been served and has not yet answered or otherwise responded. The Company intends to vigorously defend the suit.

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

In re ClassicStar Mare Lease Litigation and Gregory R. Raifman, individually and as Trustee of the Raifman Family Revocable Trust Dated 7/2/03, Susan Raifman, individually and as Trustee of the Raifman Family Revocable Trust Dated 7/2/03, and Gekko Holdings, LLC, d/b/a Gekko Breeding and Racing v. ClassicStar LLC, ClassicStar Farms, LLC, Strategic Opportunity Solutions, LLC d/b/a Buffalo Ranch, GeoStar Corporation, S. David Plummer, Spencer D. Plummer III, Tony Ferguson, Thomas Robinson, John Parrot, Karren Hendrix, Stagg Allen & Company, P.C. f/k/a Karren Hendrix & Associates, P.C., Terry L. Green, ClassicStar Farms, Inc., Gastar Exploration, Ltd. and Does 1-1,000; In the United States District Court for the Eastern District of Kentucky (Cause No. 5:07-cv-347-JMH, Master File No. 5:07-cv-353-JMH). This lawsuit was filed on February 2, 2009 in federal court in Kentucky as part of a multi-district litigation proceeding, naming the Company as one of the several defendants. The plaintiffs allege that they were induced to participate in a mare leasing program operated by the defendants, and had been promised options to convert interests in the mare leasing program for working interests in wells or shares of Company stock owned by defendants other than the Company. The plaintiffs assert several causes of action against all defendants, including violations of the RICO Act, common law fraud, negligent misrepresentation, constructive trust, unjust enrichment, and negligence. The plaintiffs also assert additional causes of action only against the ClassicStar defendants, David and Spencer Plummer, Karren Hendrix, Terry Green, Strategic Opportunity Solutions, and Does 1-1,000. On June 5, 2009, the Company filed a motion to dismiss the suit for failure to state a claim and for want of personal and subject matter jurisdiction. The motion is pending at this time and discovery is proceeding. The Company intends to vigorously defend the suit.

In re ClassicStar Mare Lease Litigation and West Hill Farms, LLC, et al. v. ClassicStar LLC, ClassicStar Farms, LLC, ClassicStar 2004, LLC, National Equine Lending Co., LLC, New NEL, LLC, GeoStar Corp., GeoStar Equine Energy, Inc., Tony Ferguson, David Plummer, ClassicStar Thoroughbreds, LLC, Spencer Plummer, Karren Hendrix Stagg Allen & Co., Thom Robinson, John Parrot, First Equine Energy Partners, LLC, Strategic Opportunity Solutions, LLC d/b/a Buffalo Ranch, ClassicStar 2005 Powerfoal Stables, LLC, ClassicStar Farms, Inc., GeoStar Financial Services Corp., Gastar Exploration, Ltd., and John Does 1-3; In the United States District Court for the Eastern District of Kentucky (Cause No. 06-243-JMH, Master File No. 5:07- cv-353-JMH). This lawsuit was filed on February 2, 2009 in federal court in Kentucky as part of a multi-district litigation proceeding, naming the Company as one of several defendants. The plaintiffs allege that they were induced to participate in a mare leasing program operated by the defendants, and had been promised options to convert interests in the mare leasing program for working interests in wells or shares of Company stock owned by defendants other than the Company. The plaintiffs assert several causes of action against the majority of the defendants, including the Company. These causes of action include violations of the RICO Act, common law fraud, negligent misrepresentation, theft by deception, unjust enrichment, conspiracy, aiding and abetting, and fraudulent transfer. The plaintiffs also assert additional causes of action against certain defendants other than the Company for breach of contract, state and federal securities fraud, anticipatory breach, and conversion. On March 19, 2009, the Company filed a motion to dismiss the suit for failure to state a claim and for want of personal and subject matter jurisdiction. The motion is pending at this time and discovery is proceeding. The Company intends to vigorously defend the suit.

In re ClassicStar Mare Lease Litigation and AA-J Breeding, LLC, Su-Sim, LLC, Derby Stakes, LLC, Uri Halfon, and Ora-Oli Halfon v. GeoStar Corp., GeoStar Financial Services Corp., First Source Wyoming, Inc., ClassicStar, LLC, ClassicStar Farms, LLC, ClassicStar Farms, Inc., Karren Hendrix, Stagg, Allen, & Company, P.C., f/k/a Karren, Hendrix & Assoc. P.C., Handler, Thayer, & Duggan, LLC, Thomas J. Handler, J.D., P.C., S. David Plummer, Spencer D. Plummer III, Tony Ferguson, Terry L. Green, and Gastar Exploration, Ltd.; In the United States District Court for the Eastern District of Kentucky (Cause No. 5:08-cv-79-JMH, Master File No. 5:07-cv-353-JMH). This lawsuit was filed on February 6, 2009 in federal court in Kentucky as part of a multi-district litigation proceeding, naming the Company as one of several defendants. The plaintiffs allege that they were induced to participate in a mare leasing program operated by the defendants, and had been promised options to convert interests in the mare leasing program for working interests in wells or shares of Company stock. The plaintiffs assert several causes of action against all defendants, including violations of the RICO Act, breach of contract, common law fraud, misrepresentation, constructive trust, unjust enrichment, accounting, and conversion. The plaintiffs also assert additional causes of action only against Karren Hendrix, Handler, Thayer, & Duggan, LLC, and Thomas J. Handler. On May 22, 2009, the Company filed a motion to dismiss the suit for failure to state a claim and for want of personal and subject matter jurisdiction. The motion is pending at this time and discovery is proceeding. The Company intends to vigorously defend the suit.

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

In re ClassicStar Mare Lease Litigation and John Goyak, Dana Goyak, John Goyak & Associates, Inc., and Jupiter Ranches, LLC, v. ClassicStar Racing Stable, LLC, ClassicStar 2003 Racing Partnership, LLC, GeoStar Financial Services Corporation, GeoStar Corporation, Private Consulting Group, Inc., S. David Plummer, Spencer Plummer, Thomas Bissmeyer, Thomas Williams, Gary Thornhill, Robert Holt, Elizabeth Holt, David Lieberman, Tony Ferguson, John Parrott, Thom Robinson, Strategic Opportunity Solutions d/b/a Buffalo Ranch, and First Source Wyoming; In the United States District Court for the Eastern District of Kentucky (Cause No. 08-cv-0053, Master File No. 5:07-cv-353-JMH). On July 15, 2009, the Court granted the plaintiffs leave to amend their pleadings in order to add the Company to the suit as one of several defendants. The plaintiffs allege that they were induced to participate in a mare leasing program operated by the defendants, and had been promised options to convert interests in the mare leasing program for working interests in wells or shares of Company stock owned by defendants other than the Company. The plaintiffs assert several causes of action including violations of the RICO Act, common law fraud, breach of contract, unjust enrichment, common law conspiracy, constructive trust, and fraud. The plaintiffs also assert additional causes of action against certain defendants other than the Company. On September 3, 2009, the Company filed a motion to dismiss the suit for failure to state a claim and for want of personal and subject matter jurisdiction. The motion is pending at this time and discovery is proceeding. The Company intends to vigorously defend the suit.

In re ClassicStar Mare Lease Litigation and James D. Lyon, Chapter 7 Trustee of ClassicStar LLC v. Tony P. Ferguson, S. David Plummer, Spencer D. Plummer III, Shane D. Plummer, Jennifer Stahle, Boyce J. Sanderson, Thomas E. Robinson, John W. Parrott, Frederick J. Lambert, ClassicStar Farms, Inc., Tartan Business L.C., Dinosaur Enterprises, L.L.C., Cadillac Farms, Inc., ClassicStar Farms LLC, GeoStar Corporation, First Source Texas, Inc., First Source Bossier, L.L.C., First Texas Gas, LP, CBM Resources Pty, Ltd., Associated Geophysical Services, Inc., Conquest Group Operating Company, West Virginia Development, Inc., West Virginia Gas Corporation, Squaw Creek Development, Inc., Arkoma Basin Development, Inc., Royalty Acquisition Company, BNG Producing & Drilling, GeoStar Financial Corporation, GeoStar Financial Services Corporation, GeoStar Leasing Corporation, Conquest Exploration, Inc., First Source Wyoming, Inc., Squaw Creek, Inc., Strategic Opportunity Solutions, LLC d/b/a Buffalo Ranch, National Equine Lending Co., L.C., New NEL, LLC, First Equine Energy Partners LLC, GeoStar Equine Energy, Inc., Private Consulting Group, Inc., Gastar Exploration, Ltd., Gastar Exploration USA, Inc. f/k/a First Sourcenergy Wyoming, Inc., Gastar Exploration Victoria, Inc. f/k/a First Sourcenergy Victoria, Inc., Gastar Exploration Texas, Inc. f/k/a First Texas Development, Inc., Gastar Exploration Texas LLC f/k/a Bossier Basin, LLC, Gastar Exploration Texas, LP f/k/a First Source Gas, LP, Gastar Exploration New South Wales, Inc. f/k/a First Sourcenergy Group, Inc., Gastar Exploration Power Pty, Ltd., Eastern Star Gas, Limited, Brookstone Development, Ltd., Debora D. Plummer, Viking Real Estate, L.C., Crown Jewels Limited Partnership, Woodford Thoroughbreds LLC and Does 1-100, including, but not limited to, various subsidiaries and affiliates of GeoStar Corporation and various subsidiaries and affiliates of Gastar Exploration, Ltd. and various entities affiliated or associated with S. David Plummer and/or Debora D. Plummer; In the United States District Court for the Eastern District of Kentucky (Cause No. 5:09-cv-215-JMH, Master File No. 5:07-cv-353-JMH). This lawsuit was filed June 16, 2009 in federal court in Kentucky as part of a multi-district litigation proceeding. The suit, brought by the Chapter 7 liquidation bankruptcy trustee for ClassicStar, names more than 50 defendants, including the Company and seven of its subsidiaries. The trustee alleges that cash from investors in ClassicStar’s mare leasing programs was systematically diverted from ClassicStar over a six year period by various defendants, among them the former officers, directors, managers, and members of ClassicStar, with the assistance and participation of various other defendants including ClassicStar affiliates; entities controlled by ClassicStar’s former officers and affiliates; GeoStar; current or former officers or shareholders of GeoStar; and GeoStar’s subsidiaries, former subsidiaries, or formerly controlled companies, including the Company and its subsidiaries. The defendants include officers and former officers of GeoStar who also served as officers or directors of the Company and its subsidiaries, or who were Company shareholders. No current officer or director of the Company has been named as a defendant. The trustee alleges that the Company and its subsidiaries were beneficiaries of an unspecified amount of the allegedly diverted ClassicStar funds while allegedly under the control of GeoStar and its officers. The trustee further alleges that the Company and its subsidiaries, along with other defendants, aided and abetted breaches of

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

fiduciary duties owed to ClassicStar by some of the defendants. The Company defendants, along with other defendants, are also alleged to have participated in, or were the beneficiaries of, or aided or abetted in, intentional or constructive fraudulent transfers of ClassicStar funds. The complaint also makes claims for an accounting and conversion of all funds diverted from ClassicStar by any of the defendants and makes certain additional state law claims, including claims under Utah’s UPUA law (similar to RICO), breach of contract, unjust enrichment, civil conspiracy, and alter ego. The trustee alleges that as a result of the acts complained of (including the alleged transfer of at least $330.0 million in cash from ClassicStar to various defendants), at least $1 billion in claims have been made against the ClassicStar estate. The trustee seeks damages in excess of $1 billion in compensatory damages, $330.0 million in punitive damages, costs, attorney’s fees, and interest. The lawsuit is consolidated for pretrial purposes in federal court in Kentucky as part of the previously disclosed multi-district litigation proceeding involving multiple actions filed by purported investors in the ClassicStar mare leasing programs, some of which name Gastar as one of several defendants. On August 19, 2009, the Company and its seven subsidiary defendants filed a motion to dismiss the trustee’s suit for failure to state a claim and for want of personal and subject matter jurisdiction. The motion is pending at this time. The Company intends to vigorously defend the suit.

In re ClassicStar Mare Lease Litigation and Stanwyck Glen Farms, LLC, Thomas E. Morello, and Denise G. Morello v. Wilmington Trust of Pennsylvania, Wilmington Trust FSB, Wilmington Trust Corp., Private Consulting Group, Inc., David S. Forman, National Equine Lending Company, LLC, GeoStar Corporation, Gastar Exploration Ltd., GeoStar Financial Services Corporation, S. David Plummer, Spencer Plummer, Tony Ferguson, and ClassicStar LLC; in the United States District Court of the Eastern District of Kentucky (Cause No. 5:09-cv-015-JMH, Master File No. 5:07-cv-353-JMH). On January 8, 2010, the plaintiffs in this case filed an amended complaint adding the Company to the suit as one of several defendants. The plaintiffs allege that they were induced to participate in a mare leasing program operated by the defendants, and had been promised options to convert interests in the mare leasing program for shares of Company stock owned by defendants other than the Company. The plaintiffs assert several causes of action including violations of the federal and New Jersey RICO Acts, common law fraud, unjust enrichment, common law conspiracy, constructive trust, accounting for shares, breach of contract, and fraud. The plaintiffs also assert additional causes of action against certain defendants other than the Company. On April 5, 2010, the Company filed a motion to dismiss the suit for failure to state a claim and for want of personal and subject matter jurisdiction. The motion is pending at this time and discovery is proceeding. The Company intends to vigorously defend the suit.

In re ClassicStar Mare Lease Litigation and Premiere Thoroughbreds, LLC, Greg Minor, and Stephanie Minor v. ClassicStar LLC, ClassicStar Farms Inc., New NEL LLC, ClassicStar Thoroughbreds LLC, Karren Hendrix Stagg Allen & Co., Terry L. Green, ClassicStar 2004, ClassicStar 2005 Powerfoal Stables LLC, Strategic Opportunity Solutions, LLC d/b/a Buffalo Ranch, GeoStar Corporation, First Equine Energy Partners LLC, GeoStar Equine Energy Inc., S. David Plummer, Tony P. Ferguson, John W. Parrott, Thomas E. Robinson, Spencer D. Plummer III, GeoStar Financial Services Corp., Gastar Exploration Ltd., and John Does; in the United States District Court of the Eastern District of Kentucky (Cause No. 5:07-cv-348-JMH, Master File No. 5:07-cv-353-JMH). On November 16, 2009, the plaintiffs in this case filed an amended complaint adding the Company to the suit as one of several defendants. The plaintiffs allege that they were induced to participate in a mare leasing program operated by the defendants and then were induced to exchange their interest in that program into units in an entity known as First Equine Energy Partners (FEEP). The FEEP units were allegedly exchangeable into shares of Gastar stock owned by GeoStar Corporation and subject to a put option provided by GeoStar Corporation. The plaintiffs assert several causes of action including violations of the federal and Florida RICO Acts, common law fraud, unjust enrichment, common law conspiracy, accounting, and negligent misrepresentation. The plaintiffs also allege securities fraud under federal and Florida law and failure to register with respect to the sale of FEEP units. The plaintiffs also assert additional causes of action against certain defendants other than the Company. On March 31, 2010, the Company filed a motion to dismiss the suit for failure to state a claim and for want of personal and subject matter jurisdiction. The motion is pending at this time and discovery is proceeding. The Company intends to vigorously defend the suit.

Midway Land & Development Inc. v. EnCana Oil & Gas (USA), Inc. v. Navasota Resources, LTD, LLP, Alta Mesa Resources LP f/k/a Navasota Resources, Inc., and Navasota Resources LTD., LLP and Gastar

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

Exploration Texas LP and Gastar Exploration, LTD.; In the District Court of Robertson County, Texas, 82ND Judicial District (Judge Stem), (Cause No. 08-12-18,265-CV). Gastar Exploration Texas LP and Gastar Exploration, LTD were served as a third-party defendant (“Counterclaim Defendant”) by EnCana Oil & Gas (USA), Inc. on September 8, 2009. The Company understands that the underlying action between Midway Land & Development Inc. and EnCana Oil & Gas (USA), Inc. has been pending since 2008. In the underlying action, Midway seeks to recover from the EnCana Defendants a 2.5% working interest on certain wells located on lands within an area of mutual interest incorporated in a Joint Operating Agreement dated July 7, 2000, between First Source Texas, Inc., as operator, and Navasota Resources, Inc. and Kentex Energy, LLC (Midway’s predecessor in interest). Under the AMI agreement, it is alleged that each of the parties has the right to acquire an interest in any lease or a mineral interest acquired by any of the other parties on land situated within the AMI (for consideration set forth in the JOA). The Gastar Defendants, among others, own or claim interest in lands that Midway contends are within the AMI. The EnCana Defendants seek declaratory relief from the Court declaring that the AMI provision in the JOA is unenforceable because it does not include a legally sufficient description of the lands within the AMI. Further, the EnCana Defendants seek to have a stipulation dated September 9, 2003 related to the AMI also declared unenforceable under the Statute of Frauds. It is alleged that the stipulations provides that Kentex (Midway’s predecessor in interest) shall be vested with an undivided five percent after payout working interest in each oil and gas well located on the leases listed on Exhibit A to the Stipulation. Gastar has answered the lawsuit and discovery is proceeding. The Company intends to vigorously defend the suit.

Gastar Exploration Texas L.P. vs. J. Ken Welch d/b/a W-S-M Oil Company, et al; Cause No. 0-09-117 in the 87th Judicial District Court of Leon County, Texas. This lawsuit, filed on March 12, 2009, is a suit for trespass to try title and, in the alternative, to quiet title, to an undivided mineral interest under several Company oil and gas leases covering approximately 4,273.7 gross acres (the “Leases”). In this suit the Company contends that certain oil and gas leases claimed by the defendants have expired according to their terms and that the defendants’ failure to release those leases constitutes a trespass upon and cloud on the Leases. The defendants have responded with a General Denial and produced a portion of the documents the Company sought in its Request for Production of Documents. They have also served their own requests for admissions and production of documents, to which the Company has responded. After repeated demands, the defendants have promised to comply and produce certain documents they obtained from third parties through depositions on written questions. Through independent discovery, the Company is gathering evidence to diminish the defendant’s interest ownership claims and will continue to vigorously pursue this claim.

The Company has been expensing legal defense costs on these proceedings as they are incurred. The Company has not accrued a liability for settlement or other resolution of these proceedings because, in the Company’s judgment, the incurrence or amount of such liabilities is either not probable or not reasonably estimable.

14. Statement of Cash Flows—Supplemental Information

The following is a summary of supplemental cash paid and non-cash transactions for the periods indicated:


	For the Three Months Ended March 31,
	2010			2009
	(in thousands)
Cash paid for interest, net of capitalized interest	$	146		$	1,099

Non-cash transactions:
Non-cash capital expenditures excluded from accounts payable and accrued drilling costs	$	3,534		$	(3,761	)
Non-cash capital expenditures excluded from accounts receivable		(1,400	)		—
Asset retirement obligation included in natural gas and oil properties		10			125
Drilling advances application		150			2,416

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

15. Comprehensive Income (Loss)

The information set forth in this Note is restated herein. Please read Note 16 “Restatement of Previously Issued Financial Statements” for further discussion of the restatement.

The Company’s comprehensive income (loss) for the periods indicated is as follows:


	For the Three Months Ended March 31,
	2010
	(Restated - See Note 16)		2009
	(in thousands)
Net income (loss)	$	9,393	$	(70,187	)
Change in:
Commodity hedging activities—current period reclassification to earnings		—		(856	)
Foreign currency translation adjustments		—		2

Comprehensive income (loss)	$	9,393	$	(71,041	)

16. Restatement of Previously Issued Financial Statements

Subsequent to the filing of the Company’s Quarterly Report on Form 10-Q for the period ended March 31, 2010, in conjunction with its review of the results of operations and hedging in connection with the quarterly review at June 30, 2010, management discovered that at March 31, 2010, the commodity derivative premium payables were inappropriately netted with the receivables from commodity derivative contracts resulting in an incorrect marked to market value for commodity derivative assets and understated unrealized natural gas hedge gains for the period. As a result of its analysis of the accounting error, management determined that the current receivables from commodity derivative contracts, the long-term receivables from commodity derivative contracts and the unrealized natural gas hedge gain were understated by $1.9 million, $7.5 million and $9.4 million, respectively, and total equity was understated by $9.4 million for the three months ended March 31, 2010. See Note 6 “Fair Value Measurements,” Note 7 “Derivative Instruments and Hedging Activities,” Note 12 “Earnings Per Share” and Note 15 “Comprehensive Income (Loss).” There was no impact on cash flows provided by operating activities or on any other aspect of the Company’s business.

Accordingly, the Company is hereby restating its Condensed Consolidated Balance Sheet as of March 31, 2010, Condensed Consolidated Statement of Operations for the Three Months Ended March 31, 2010, Condensed Consolidated Statement of Cash Flows for the Three Months Ended March 31, 2010 and related Notes to our Condensed Consolidated Financial Statements as set forth herein.

The following tables display the Company’s as adjusted Condensed Consolidated Balance Sheet, Statement of Operations and Statement of Cash Flows for March 31, 2010 as if the Company had included the adjustments to the commodity derivative assets and the unrealized natural gas hedge gains.

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS—(Continued)

Condensed Consolidated Balance Sheet


	As of March 31, 2010
	As Reported			Adjustment		Restated
	(in thousands)
CURRENT ASSETS:
Receivables from commodity derivative contracts	$	8,499		$	1,918	$	10,417
Total current assets		104,757			1,918		106,675
OTHER ASSETS:
Receivables from commodity derivative contracts	$	4,564		$	7,448	$	12,012
Total other assets		5,382			7,448		12,830
TOTAL ASSETS	$	284,259		$	9,366	$	293,625
SHAREHOLDERS’ EQUITY:
Accumulated deficit	$	(119,668	)	$	9,366	$	(110,302	)
Total shareholders’ equity		165,642			9,366		175,008
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	284,259		$	9,366	$	293,625

Condensed Consolidated Statement of Operations


	For the Three Months Ended March 31, 2010
	As Reported			Adjustment		Restated
	(in thousands, except per share data)
REVENUES:
Unrealized natural gas hedge gain (loss)	$	12		$	9,366	$	9,378
Total revenues		6,770			9,366		16,136
INCOME (LOSS) FROM OPERATIONS	$	(2,003	)	$	9,366	$	7,363
INCOME (LOSS) BEFORE PROVISION FOR INCOME TAXES	$	(822	)	$	9,366	$	8,544
NET INCOME (LOSS)	$	27		$	9,366	$	9,393
NET INCOME (LOSS) PER SHARE:
Basic	$	0.00		$	0.19	$	0.19
Diluted	$	0.00		$	0.19	$	0.19

Condensed Consolidated Statement of Cash Flows


	For the Three Months Ended March 31, 2010
	As Reported			Adjustment			Restated
	(in thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$	27		$	9,366		$	9,393
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Unrealized natural gas hedge (gain) loss	$	(12	)	$	(9,366	)	$	(9,378	)
Net cash provided by operating activities	$	7,370		$	—		$	7,370

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Amendment does not reflect events occurring after the original filing of the Form 10-Q on May 6, 2010 and does not modify or update the disclosures presented in the Form 10-Q in any way, other than as described in Part I, Item 1. “Financial Statements, Note 16—Restatement of Previously Issued Financial Statements” to our condensed consolidated financial statements. The original Form 10-Q, as amended and restated in pertinent part hereby, includes forward-looking information regarding Gastar that is intended to be covered by the “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995, Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements other than statements of historical fact included or incorporated by reference in the Form 10-Q, as amended hereby, are forward-looking statements, including without limitation all statements regarding future plans, business objectives, strategies, expected future financial position or performance, expected future operational position or performance, budgets and projected costs, future competitive position, or goals and/or projections of management for future operations. In some cases, you can identify a forward-looking statement by terminology such as “may,” “will,” “could,” “should,” “expect,” “plan,” “project,” “intend,” “anticipate,” “believe,” “estimate,” “predict,” “potential,” “pursue,” “target” or “continue,” the negative of such terms or variations thereon, or other comparable terminology.

The forward-looking statements contained in this Form 10-Q, as amended hereby, are largely based on our expectations and beliefs concerning future developments and their potential effect on us, which reflect certain estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions, operating trends, and other factors. Forward-looking statements may include statements that relate to, among other things, our:

•

Financial position;

•

Business strategy and budgets;

•

Anticipated capital expenditures;

•

Drilling of wells;

•

Natural gas and oil reserves;

•

Timing and amount of future production of natural gas and oil;

•

Operating costs and other expenses;

•

Cash flow and anticipated liquidity;

•

Prospect development; and

•

Property acquisitions and sales.

Although we believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control. As such, management’s assumptions about future events may prove to be inaccurate. For a more detailed description of the risks and uncertainties involved, see Part II, Item 1A. “Risk Factors” of this Form 10-Q, as amended hereby. We do not intend to publicly update or revise any forward-looking statements as a result of new information, future events, changes in circumstances, or otherwise. These cautionary statements qualify all forward-looking statements attributable to us or persons acting on our behalf. Management cautions all readers that the forward-looking statements contained in this report are not guarantees of future performance, and we cannot assure any reader that such statements will be realized or that the events and circumstances they describe will occur. Factors that could cause actual results to differ materially from those anticipated or implied in the forward-looking statements herein include, but are not limited to:

•

Low and/or declining prices for natural gas and oil;

•

Demand for natural gas and oil;

•

Natural gas and oil price volatility;

•

The risks associated with exploration, including cost overruns and the drilling of non-economic wells or dry wells;

•

Ability to raise capital to fund capital expenditures or repay or refinance debt upon maturity;

•

The ability to find, acquire, market, develop and produce new natural gas and oil properties;

•

Uncertainties in the estimated quantities of natural gas and oil reserves and in the projection of future rates of production and timing of development expenditures of proved reserves;

•

Operating hazards inherent to the natural gas and oil business;

•

Down hole drilling and completion risks that are generally not recoverable from third parties or insurance;

•

Potential mechanical failure or under-performance of significant wells or pipeline mishaps;

•

Adverse weather conditions;

•

Availability and cost of material and equipment, such as drilling rigs and transportation pipelines;

•

The number of well locations to be drilled and the time frame in which they will be drilled;

•

Delays in anticipated start-up dates;

•

Actions or inactions of third-party operators of our properties;

•

Ability to find and retain skilled personnel;

•

Strength and financial resources of competitors;

•

Potential defects in title to our properties;

•

Federal and state regulatory developments and approvals;

•

Losses possible from pending or future litigation;

•

Environmental risks; and

•

Worldwide political and economic conditions.

Other factors that could affect our financial performance or cause our actual results to differ materially from our projected results are described under (i) Part II, Item 1A. “Risk Factors” and elsewhere in this Form 10-Q, as amended hereby, (ii) Part I, Item 1A. “Risk Factors” and elsewhere in our 2009 Form 10-K (iii) our reports and registration statements filed from time to time with the SEC and (iv) other announcements we make from time to time.

You should not unduly rely on these forward-looking statements in this Form 10-Q, as amended hereby, as they speak only as of the date of the original filing of the Form 10-Q. Except as required by law, we undertake no obligation to publicly update, revise or release any revisions to these forward-looking statements after the date they are made, whether as a result of new information, future events or otherwise, to reflect events or circumstances occurring after the date of the original filing of the Form 10-Q or to reflect the occurrence of unanticipated events.

Overview

We are an independent energy company engaged in the exploration, development and production of natural gas and oil in the United States. Our principal business activities include the identification, acquisition, and subsequent exploration and development of natural gas and oil properties with an emphasis on prospective deep structures identified through seismic and other analytical techniques as well as unconventional natural gas reserves, such as shale resource plays. We are pursuing natural gas exploration in the deep Bossier gas play in the Hilltop area of East Texas and the Marcellus Shale in the Appalachian area of West Virginia and central and southwestern Pennsylvania. We also conduct CBM development activities within the Powder River Basin of Wyoming and Montana. We are a Canadian corporation incorporated in Alberta in 1987. We are publicly traded on the NYSE Amex under the ticker symbol “GST”.

Natural Gas and Oil Activities

The following provides an overview of our major natural gas and oil projects. While actively pursuing specific exploration and development activities in each of the following areas, there is no assurance that new drilling opportunities will be identified or that any new drilling opportunities will be successful if drilled.

Hilltop Area, East Texas. The majority of our activities have been in the Bossier play in the Hilltop area of East Texas approximately midway between Dallas and Houston in Leon and Robertson Counties. As of March 31, 2010, our acreage position in the play was approximately 31,600 gross (16,400 net) acres. Wells in this area target multiple potentially productive natural gas formations and are typically characterized by high initial production and attractive long-lived per well reserves.

In late October 2009, we began drilling the Donelson #4 well, a vertical lower Bossier test. The well was originally drilled to a total depth of approximately 19,000 feet; however, while attempting to log the well, the drill pipe became stuck due to hole stability issues. The well was sidetracked, and while re-drilling, the well experienced a significant gas kick and had to be plugged back to approximately 15,600 feet to re-drill to a revised total depth of 18,800 feet. This second sidetrack operation is expected to be completed during the first half of May and will require additional costs of approximately $4.5 million gross ($3.8 million net). The revised estimate to drill and complete the Donelson #4 well, net of estimated reimbursement under existing well control insurance policies, is approximately $15.3 million gross ($10.2 million net). Gastar has a 67% before payout working interest and an approximate 50% before payout net revenue interest in the well.

In March 2010, we commenced a recompletion of the Belin#1 well in the “Lanier” sand at approximately 16,700 feet. The zone was fracture stimulated and during initial flow back operations the well produced significant amounts of formation sand. It appears that the formation sand production coincided with a casing failure at approximately 16,700 feet. We have successfully milled through the damaged portion of the casing and are now evaluating options to repair the casing and return the well to production. If the casing damage cannot be repaired, it is possible that we will not be able to produce the Belin #1 well from any of the previously completed zones and will have to partially abandon the wellbore. If the lower portion of the wellbore has to be abandoned, we will evaluate utilizing the upper well bore to re-drill the well to the original depth. Gastar has a 50% before payout working interest and an approximate 34% before payout net revenue interest in the well.

In addition to the delays in the Donelson #4 and Belin #1 wells, we had down-hole salting and scale problems that significantly reduced current quarter production in two of our higher producing East Texas wells. Subsequent to quarter end, these wells have been returned to production. For the three months ended March 31, 2010, net production from the Hilltop area averaged 17.0 MMcfe per day.

Appalachia—West Virginia and Central and Southwestern Pennsylvania. The Marcellus Shale is Middle Devonian aged shale that underlies much of Pennsylvania, New York, Ohio, West Virginia and adjacent states. The depth of the Marcellus Shale and its low permeability make the Marcellus Shale an unconventional exploration target. Advancements in two technologies, stimulation and horizontal drilling, have produced promising results in the Marcellus Shale. These developments have resulted in increased leasing and drilling activity in the area. As of March 31, 2010, our acreage position in the play was approximately 37,800 gross (34,100 net) acres, of which the majority is considered to be in the core, over-pressured area of the Marcellus play and is in close proximity to wells being drilled by other operators.

In October 2009, we commenced drilling our first vertical Marcellus Shale well, the Yoho #1. We drilled the well to a depth of 6,600 feet, and it was completed and tested in January 2010. It tested at a stabilized gross rate of 1.5 MMcf and 120 barrels of condensate per day, with no water production at approximately 1,000 psi of flowing tubing pressure. We currently are waiting for a connection to a pipeline and do not expect natural gas sales until late third quarter 2010.

During the three months ended March 31, 2010, we drilled 1 gross (1.0 net) shallow vertical well resulting in total shallow wells drilled by us to date of 16 gross (14.8 net) in the area. Currently, twelve are on production, and the remaining four wells are scheduled to be on production in the next 30 days. This shallow well drilling program continues to be conducted to hold certain leases by production.

For the three months ended March 31, 2010, net production from the Appalachia area averaged approximately 0.4 MMcfe per day.

Coalbed Methane—Powder River Basin, Wyoming and Montana. We own an approximate 40% average working interest in approximately 40,700 gross (17,200 net) acres in the Powder River Basin of Wyoming and Montana. As a result of decreased drilling activity and curtailments during 2009 due to lower realized gas prices, Powder River Basin production averaged 2.2 MMcfe per day for the three months ended March 31, 2010.

Results of Operations

The following is a comparative discussion of the results of operations for the periods indicated. It should be read in conjunction with the condensed consolidated financial statements and the related notes to the condensed consolidated financial statements found elsewhere in this Amendment.

The following table provides information about production volumes, average prices of natural gas and oil and operating expenses for the periods indicated:


	For the Three Months Ended
	March 31,
	2010		2009
Production:
Natural gas (MMcf)		1,753		2,693
Oil (MBbl)		2		1
Total production (MMcfe)		1,764		2,698
Total (MMcfed)		19.6		30.0

Average sales price per unit:
Natural gas per Mcf, excluding impact of realized hedging activities	$	4.35	$	3.37
Natural gas per Mcf, including impact of realized hedging activities		3.78		4.99
Oil per Bbl		72.01		39.47

Selected operating expenses (in thousands):
Production taxes	$	123	$	157
Lease operating expenses		1,743		1,877
Transportation, treating and gathering		1,249		493
Depreciation, depletion and amortization		1,731		7,999
General and administrative expense		3,832		2,958

Selected operating expenses per Mcfe:
Production taxes	$	0.07	$	0.06
Lease operating expenses		0.99		0.70
Transportation, treating and gathering		0.71		0.18
Depreciation, depletion and amortization		0.98		2.96
General and administrative expense		2.17		1.10

Three Months Ended March 31, 2010 compared to the Three Months Ended March 31, 2009

Revenues. Substantially all of our revenues are derived from the production of natural gas in the United States. Natural gas and oil revenues were $6.8 million for the three months ended March 31, 2010, down from $13.5 million for the three months ended March 31, 2009. The decrease in revenues was the result of a 35% decrease in volumes and a 23% decrease in prices. Average daily production on an equivalent basis was 19.6 MMcfe per day for the three months ended March 31, 2010 compared to 30.0 MMcfe per day for the same period in 2009. Of the decrease in volumes, 80% was due to lower East Texas production primarily related to the first quarter of 2009 benefitting from Belin #1 initial flush production and 20% was due to a Wyoming production decline.

During the three months ended March 31, 2010, approximately 70% of our natural gas production was hedged. The realized effect of hedging on natural gas sales was a decrease of $1.0 million in revenues resulting in a decrease in total price received from $4.35 per Mcf to $3.78 per Mcf. The realized hedge impact includes $1.0 million of amortization of prepaid put purchase premiums. Excluding the non-cash put premium amortization, realized effect of hedging would have been a gain of $41,000 comprised of $739,000 of NYMEX hedge gains offset by $698,000 of regional basis losses. For the remainder of 2010, we have approximately 55% of our estimated future natural gas production hedged at an average NYMEX price of $5.83.

Unrealized natural gas hedge income was $$9.4 million for the three months ended March 31, 2010 compared to an unrealized natural gas hedge loss of $196,000 for the three months ended March 31, 2009. The increase in unrealized natural gas hedge impact was the result of a hedge benefit as a result of lower future NYMEX gas prices offset by losses related to projected basis differentials.

Production taxes We reported production taxes of $123,000 for the three months ended March 31, 2010 compared to $157,000 for the three months ended March 31, 2009. The decrease in production taxes was primarily the result of lower revenues in Wyoming due to lower production volumes.

Lease operating expenses. We reported lease operating expenses of $1.7 million for the three months ended March 31, 2010 down from $1.9 million for the three months ended March 31, 2009. This decrease was primarily due to a decline in workover expenses of $118,000 and lower costs in Wyoming. Our lease operating expenses were $0.99 per Mcfe for the three months ended March 31, 2010 compared to $0.70 per Mcfe for the same period in 2009. The increase in the rate per Mcfe was primarily due to lower production volumes.

Transportation, treating and gathering. We reported transportation expenses of $1.2 million for the three months ended March 31, 2010 up from $493,000 for the three months ended March 31, 2009. This increase was primarily due to gathering charges in Texas under the Hilltop Gathering Agreement effective November 2009 partially offset by lower costs in Wyoming. The current quarter included a true up charge under the Hilltop Gathering Agreement based on a minimum volume requirement of $391,000.

Depreciation, depletion and amortization. We reported depreciation, depletion and amortization (“DD&A”) expense of $1.7 million for the three months ended March 31, 2010 down from $8.0 million for the three months ended March 31, 2009. The decrease in DD&A expense was the result of a 67% decrease in the DD&A rate per Mcfe and a 35% decrease in production. The DD&A rate for the three months ended March 31, 2010 was $0.98 per Mcfe compared to $2.96 per Mcfe for the same period in 2009. The decrease in the rate is primarily due to lower proved costs as a result of a ceiling impairment recorded at March 31, 2009 and gathering sales proceeds credited to proved property costs in late 2009 combined with slightly higher natural gas prices resulting in higher proved reserves.

Impairment of natural gas and oil properties. We did not report an impairment of natural gas and oil properties for the three months ended March 31, 2010 due to lower proved property costs and higher natural gas and oil prices compared to the same period in 2009. For the three months ended March 31, 2009, we reported an impairment of natural gas and oil properties of $68.7 million which resulted from a significant decline in natural gas prices at March 31, 2009.

General and administrative. We reported general and administrative expenses of $3.8 million for the three months ended March 31, 2010 up from $3.0 million for the three months ended March 31, 2009. Non-cash stock-based compensation expense, which is included in general and administrative expense, was $759,000 and $1.4 million for the three months ended March 31, 2010 and 2009, respectively. The decrease in stock-based compensation expense is due primarily to the decision in March 2009 to pay the 2008 management bonuses of $801,000 in vested restricted common shares in lieu of cash. Excluding stock-based compensation expense, general and administrative expense increased $1.5 million to $3.1 million for the three months ended March 31, 2010 compared to March 31, 2009. This increase is primarily due to higher legal costs of $831,000 related to ongoing litigation matters and lower personnel costs for the three months ended March 31, 2009 due to the March 2009 payment of 2008 management bonuses in restricted common shares.

Interest expense. We reported interest expense of $78,000 for the three months ended March 31, 2010 compared to $1.2 million for the three months ended March 31, 2009. The decrease in interest expense was primarily the result of lower debt outstanding due to the payoff of substantially all outstanding debt during 2009.

Investment income and other. We reported investment income of $792,000 for the three months ended March 31, 2010 compared to $13,000 for the three months ended March 31, 2009. The increase in investment income is primarily due to interest earned on the Australian term deposit established in conjunction with the sale of the Australian properties for the future tax payment on the sale.

Warrant derivative gain. For the three months ended March 31, 2010 we reported a $148,000 non-cash gain related to the fair value measurement of our warrants outstanding.

Foreign transaction gain (loss). We reported a foreign transaction gain of $319,000 for the three months ended March 31, 2010 compared to a loss of $3,000 for the three months ended March 31, 2009. The increase in the foreign transaction gain was due to the increase in Australian denominated cash and cash term deposit balances primarily due to the sale of the Australian properties partially offset by the increase in Australian denominated tax liability. At March 31, 2010, approximately $78.0 million of our cash and cash term deposit continue to be denominated in Australian dollars along with $76.8 million of future Australian income tax liability due June 1, 2010.

Liquidity and Capital Resources

Overview. Our primary sources of liquidity and capital resources are internally generated cash flows from operating activities or asset sales, availability under our revolving credit facility, and access to capital markets, to the extent available. The capital markets, as they relate to us, have been adversely impacted by the recent financial crisis, the possibility of a continuing world recession that may extend for a long period into the future, the potential lack of liquidity in the banking system and the potential unavailability and cost of credit. Though recently there has been some improvement in the capital markets, there is no guarantee that such will continue. We continually evaluate our capital needs and compare them to our capital resources and ability to raise funds in the financial markets. We adjust capital expenditures in response to changes in natural gas and oil prices, drilling results and cash flow.

For the three months ended March 31, 2010, we reported cash flows provided by operating activities of $7.4 million, net cash used in investing activities of $460,000 and net cash used in financing activities of $17.0 million. As a result of these activities, our cash and cash equivalents balance decreased by $10.1 million, resulting in a March 31, 2010 cash and cash equivalents balance of $11.7 million.

At March 31, 2010, we had a net working capital surplus of approximately $5.1 million.

Future capital and other expenditure requirements. Capital expenditures for the remainder of 2010 are projected to be approximately $45.0 million, consisting of $27.7 million in East Texas, $14.3 million in Appalachia in the Marcellus Shale, $1.1 million in the Powder River Basin and an additional $1.9 million for capitalized interest and other costs. We plan on funding this capital activity through our existing cash balances, internally generated cash flows from operating activities and access to availability under our revolving credit facility. The majority of projected capital expenditures are operated by us and thus, we can adjust capital expenditures for changes in commodity prices, cash flows from operating activities or availability under the revolving credit facility.

Commodity Hedging Activities. Our operating cash flow is sensitive to many variables, the most significant of which is the volatility of prices for natural gas. Prices for these commodities are determined primarily by prevailing market conditions including national and worldwide economic activity, weather, infrastructure capacity to reach markets, supply levels and other variable factors. These factors are beyond our control and are difficult to predict.

To mitigate some of the potential negative impact on cash flows caused by changes in natural gas prices, we have entered into financial commodity costless collars, index swaps, basis and fixed price swaps and put and call options to hedge natural gas price risk. We typically hedge a fixed price for natural gas at our sales points of NYMEX less basis to mitigate the risk of differentials to the NYMEX Henry Hub Index and our sales points. In addition to NYMEX swaps and collars and fixed price swaps, we also have entered into basis only swaps. With a basis only swap, we have hedged the difference between the NYMEX price and the price received for our natural gas production at the specific delivery location. See Item 1. “Financial Statements, Note 7—Derivative Instruments and Hedging Activity.”

At March 31, 2010, the estimated fair value of all of our commodity derivative instruments was a net asset of $15.1 million, comprised of current and noncurrent assets and liabilities. In conjunction with certain commodity derivative hedging activity, we deferred the payment of certain put premiums for the production month period July 2010 through December 2012. At March 31, 2010, we had a current commodity derivative premium payable of $1.9 million and a long-term commodity derivative premium payable of $7.4 million. The put premium liabilities become payable monthly as the hedge production month becomes the prompt production month.

By removing the price volatility from a portion of our natural gas for 2010, 2011 and 2012, we have mitigated, but not eliminated, the potential effects of changing prices on our operating cash flows for those periods. While mitigating negative effects of falling commodity prices, certain derivative contracts also limit the benefits we could receive from increases in commodity prices.

As of March 31, 2010, all of our economic derivative hedge positions were with a multinational energy company or large financial institutions, which are not known to us to be in default on their derivative positions. Credit support for our open derivatives at March 31, 2010 is provided under the revolving credit facility through inter-creditor agreements or under a $100,000 letter of credit. During April 2010, the letter of credit was cancelled. We are exposed to credit risk to the extent of non-performance by the counterparties in the derivative contracts discussed above; however, we do not anticipate non-performance by such counterparties.

Revolving Credit Facility. At March 31, 2010, there were no amounts outstanding under the revolving credit facility except for a $100,000 letter of credit to support our hedging activities. During April 2010, the $100,000 letter of credit was cancelled. Currently, our availability under our borrowing base is $47.5 million but is subject to change based on the results of the current redetermination, which is scheduled to be completed during the second quarter of 2010. Borrowings under the facility bear interest, at our election, at the prime rate or LIBO rate plus an applicable margin. Pursuant to the revolving credit facility, the applicable interest rate margin varies from 1.0% to 2.0% in the case of borrowings based on the prime rate and from 2.5% to 3.5% in the case of borrowings based on the LIBO rate, depending on the utilization percentage in relation to the borrowing base. Under the revolving credit facility, we are subject to certain financial covenants, including interest coverage ratio, a total net indebtedness to EBITDA ratio and current ratio requirement.

As of March 31, 2010, we were in compliance with all financial covenants under the revolving credit facility, including interest coverage ratio, a total net indebtedness to EBITDA ratio and current ratio requirements. See Item 1. “Financial Statements, Note 5—Long-Term Debt.”

Off -Balance Sheet Arrangements

As of March 31, 2010, we had no off- balance sheet arrangements. We have no plans to enter into any off- balance sheet arrangements in the foreseeable future.

Commitments and Contingencies

As is common within the industry, we have entered into various commitments and operating agreements related to the exploration and development of and production from proved natural gas properties. It is management’s belief that such commitments will be met without a material adverse effect on our financial position, results of operations or cash flows.

We are party to various litigation matters and administrative claims arising out of the normal course of business. Although the ultimate outcome of each of these matters cannot be absolutely determined and the liability the Company may ultimately incur with respect to any one of these matters in the event of a negative outcome may be in excess of amounts currently accrued with respect to such matters, management does not believe any such matters will have a material adverse effect on our financial position, results of operations or cash flows.

Critical Accounting Policies and Estimates

The preparation of financial statements in conformity with US GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses, contingent assets and liabilities and the related disclosures in the accompanying condensed consolidated financial statements. Changes in these estimates and assumptions could materially affect our financial position, results of operations or cash flows. Management considers an accounting estimate to be critical if:

•

It requires assumptions to be made that were uncertain at the time the estimate was made; and

•

Changes in the estimate or different estimates that could have been selected could have a material impact on our consolidated results of operations or financial condition.

Significant accounting policies that we employ and information about the nature of our most critical accounting estimates, our assumptions or approach used and the effects of hypothetical changes in the material

assumptions used to develop each estimate are presented in Item 1. “Financial Statements, Note 2—Summary of Significant Accounting Policies” of this Amendment and in Part II, Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies and Estimates” included in our 2009 Form 10-K.

Recent Accounting Developments

For a discussion of recent accounting developments, see Item 1. “Financial Statements, Note 2—Summary of Significant Policies” of this Amendment.

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

Commodity Price Risk

Our major commodity price risk exposure is to the prices received for our natural gas production and our results of operations and operating cash flows are affected by changes in market prices. Realized commodity prices received for our production are the spot prices applicable to natural gas in the region produced. Prices received for natural gas are volatile and unpredictable and are beyond our control. To mitigate a portion of the exposure to adverse market changes, we have entered into various derivative instruments. For the three months ended March 31, 2010, a 10% change in the prices received for natural gas production (before hedging activities) would have had an approximate $776,000 impact on our revenues prior to hedge transactions to mitigate our commodity pricing risk. See Item 1. “Financial Statements, Note 7—Derivative Instruments and Hedging Activity” to our condensed consolidated financial statements for additional information regarding our hedging activities. (The information in Note 7 is restated herein. See Note 16 “Restatement of Previously Issued Financial Statements for further discussion of the restatement.)

Interest Rate Risk

At March 31, 2010, we had no debt outstanding. We currently do not use interest rate derivatives to mitigate our exposure to the volatility in interest rates, including under our revolving credit facility.

Foreign Currency Exchange Risk

During 2009, we sold all of our Australian Assets. As a result, all of our future revenues and capital expenditures and substantially all of our expenses will be in US dollars, thus limiting our exposure to foreign currency exchange risk. As part of the sale of the Australian Assets, we have a receivable for AU$2.0 million ($1.8 million). This receivable exposes us to limited foreign currency exchange risk. Our term deposit of AU$83.3 million ($76.7 million) is pledged to pay accrued Australian taxes that are denominated in Australian dollars, thus negating any ultimate foreign currency exchange risk.

Item 4.

Controls and Procedures

Management’s Evaluation on the Effectiveness of Disclosure Controls and Procedures

We maintain disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act, designed to provide reasonable assurance that the information required to be disclosed by us in the reports filed or submitted by us under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including the Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.

As discussed elsewhere in this Amendment, in conjunction with its review of our results of operations and hedging in connection with the quarterly review at June 30, 2010, management determined that at March 31, 2010, the commodity derivative premium payable was inappropriately netted with the receivables from commodity derivative contracts resulting in an incorrect marked to market value for commodity derivative assets and understatement of unrealized natural gas hedge gains for the period. As a result of its analysis of this accounting error, management also determined that certain previously issued unaudited interim financial statements as of and

for the three months ended March 31, 2010 included in the Form 10-Q should no longer be relied upon and therefore required restatement. Please read Part I, Item 1. “Financial Statements, Note 16—Restatement of Previously Issued Financial Statements” to our condensed consolidated financial statements for further discussion of the restatement.

Auditing Standard No. 5 issued by the Public Company Accounting Oversight Board indicates that a restatement of previously issued financial statements is a “indicator that a material weakness in internal control over financial reporting exists.” Accordingly, we performed a re-evaluation, under the supervision and with the participation of management, including our Chief Executive Officer and Chief Financial Officer (our principal executive officer and principal financial officer, respectively), of the effectiveness of our disclosure controls and procedures under the Exchange Act as of the end of the period covered by this Amendment. As part of our evaluation, we reviewed the circumstances surrounding the restatement of our previously issued unaudited interim financial statements as of and for the three months ended March 31, 2010.

After giving effect to the restatement described above and based upon the evaluation of our disclosure controls and procedures as of the end of the period covered by this Form 10-Q, as amended hereby, conducted by our management, our Chief Executive Officer and Chief Financial Officer have concluded that as of March 31, 2010 our disclosure controls and procedures were not effective in that there was a failure to properly record and report the commodity derivative assets and unrealized natural gas hedge gain for the period.

Based upon the foregoing, management took immediate steps to strengthen our internal control over financial reporting. Our disclosure controls and procedures now include additional analysis of the reported commodity derivative assets and liabilities to ensure all amounts are reported accurately and additional levels of review by our accounting personnel and management.

After giving effect to the restatement contained in this Amendment and the remediation efforts to our internal controls described above, our Chief Executive Officer and Chief Financial Officer have concluded that our current disclosure controls and procedures were effective as of the filing date of this Amendment in providing reasonable assurance that the information required to be disclosed by us in our periodic SEC reports filed or submitted by us under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including the Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. Accordingly, management has concluded that the financial statements included in this Amendment present fairly in all material respects our financial condition, results of operations and cash flows for the periods presented.

Changes in Internal Control over Financial Reporting

We have implemented a number changes in our internal control structure to address the internal control weakness described above. There were no other changes in our internal control over financial reporting that occurred during the three month period covered by the Form 10-Q or as of the date of this Amendment beyond the additional controls discussed above, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1.

Legal Proceedings

A discussion of current legal proceedings is set forth in Part I, Item 1. “Financial Statements, Note 13—Commitments and Contingencies” to our condensed consolidated financial statements in this Form 10-Q, as amended hereby.

Item 1A.

Risk Factors

Information about material risks related to our business, financial condition and results of operations for the three months ended March 31, 2010, does not materially differ from that set out under Part I, Item 1A. “Risk Factors” in our 2009 Form 10-K. You should carefully consider the factors discussed in our 2009 Form 10-K. These risks are not the only risks facing our Company. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition, operating results and cash flows.

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3.

Defaults Upon Senior Securities

None.

Item 4.

(Removed and Reserved).

Item 5.

Other Information

None.

Item 6.

Exhibits

The following is a list of exhibits filed or furnished (as indicated) as part of the Form 10-Q, as amended hereby. Where so indicated by a note, exhibits which were previously filed are incorporated herein by reference.


Exhibit Number		Description

10.35		Agreement dated January 12, 2010, by and among Gastar Exploration Ltd,, Palo Alto Investors, LLC and certain of its affiliates (incorporated herein by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K dated January 14, 2010. File No. 001-132714).

31.1†		Certification of Periodic Financial Reports by Chief Executive Officer in satisfaction of Section 302 of the Sarbanes-Oxley Act of 2002.

31.2†		Certification of Periodic Financial Reports by Chief Financial Officer in satisfaction of Section 302 of the Sarbanes-Oxley Act of 2002.

32.1††		Certification of Periodic Financial Reports by Chief Executive Officer in satisfaction of Section 906 of the Sarbanes-Oxley Act of 2002.

32.2††		Certification of Periodic Financial Reports by Chief Financial Officer in satisfaction of Section 906 of the Sarbanes-Oxley Act of 2002.

†	Filed herewith.

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, thereunto duly authorized.


	GASTAR EXPLORATION LTD.

Date: July 29, 2010	By:	/S/ J. RUSSELL PORTER
		J. Russell Porter
		President and Chief Executive Officer
		(Duly authorized officer and principal executive officer)

Date: July 29, 2010	By:	/S/ MICHAEL A. GERLICH
		Michael A. Gerlich
		Vice President and Chief Financial Officer
		(Duly authorized officer and principal financial and accounting officer)

EXHIBIT INDEX


Exhibit Number		Description

10.35		Agreement dated January 12, 2010, by and among Gastar Exploration Ltd,, Palo Alto Investors, LLC and certain of its affiliates (incorporated herein by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K dated January 14, 2010. File No. 001-132714).

31.1†		Certification of Periodic Financial Reports by Chief Executive Officer in satisfaction of Section 302 of the Sarbanes-Oxley Act of 2002.

31.2†		Certification of Periodic Financial Reports by Chief Financial Officer in satisfaction of Section 302 of the Sarbanes-Oxley Act of 2002.

32.1†		Certification of Periodic Financial Reports by Chief Executive Officer in satisfaction of Section 906 of the Sarbanes-Oxley Act of 2002.

32.2†		Certification of Periodic Financial Reports by Chief Financial Officer in satisfaction of Section 906 of the Sarbanes-Oxley Act of 2002.

†	Filed herewith.

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