Gastar Exploration (GSTCQ) 10-Q 2008 Q1 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2008

OR

¨ 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)	(IRS 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 is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See definition of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer  ¨    Accelerated filer  x    Non-accelerated filer  ¨    Smaller reporting company  ¨

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 common shares, no par value per share, as of May 12, 2008 was 208,194,570.

GASTAR EXPLORATION LTD.

QUARTERLY REPORT ON FORM 10-Q

FOR THE THREE MONTHS ENDED MARCH 31, 2008

TABLE OF CONTENTS

		Page
	PART I – FINANCIAL INFORMATION
Item 1.	Financial Statements
	Condensed Consolidated Balance Sheets as of March 31, 2008 and December 31, 2007	1
	Condensed Consolidated Statements of Operations for the Three Months Ended March 31, 2008 and 2007	2
	Condensed Consolidated Statements of Cash Flows for the Three Months Ended March 31, 2008 and 2007	3
	Notes to the Condensed Consolidated Financial Statements	4
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	26
Item 3.	Quantitative and Qualitative Disclosure of Market Risk	32
Item 4.	Controls and Procedures	32
	PART II – OTHER INFORMATION
Item 1.	Legal Proceedings	33
Item 1A.	Risk Factors	33
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	33
Item 3.	Default Upon Senior Securities	33
Item 4.	Submission of Matters to a Vote of Security Holders	33
Item 5.	Other Information	33
Item 6.	Exhibits	33
	SIGNATURES	34

Unless otherwise indicated or required by the context, (i) “we”, “us”, and “our” refer to Gastar Exploration Ltd. and its subsidiaries and predecessors, (ii) all dollar amounts appearing in this Quarterly Report on Form 10-Q (“Form 10-Q”) are stated in United States (“U.S.”) dollars unless specifically noted in Canadian dollars (“CDN$”) or Australian dollars (“AUD$”), and (iii) all financial data included in this Form 10-Q has 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 atwww.gastar.com. The information on our website is neither incorporated into, nor part of, this report. 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 United States Securities and Exchange Commission (“SEC”). Information is also available atwww.sec.gov for United States filings and on SEDAR atwww.sedar.com for Canadian filings.

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GASTAR EXPLORATION LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

ASSETS

	March 31, 2008			December 31, 2007
	(Unaudited)
	(in thousands)
CURRENT ASSETS:
Cash and cash equivalents	$	78,968		$	85,854
Accounts receivable, net of allowance for doubtful accounts of $4.3 million for both periods		8,769			4,828
Due from related parties		1,611			904
Prepaid expenses		1,117			1,235
Total current assets		90,465			92,821
PROPERTY, PLANT AND EQUIPMENT:
Natural gas and oil properties, full cost method of accounting:
Unproved properties, not being amortized		84,279			69,844
Proved properties		249,490			247,372
Total natural gas and oil properties		333,769			317,216
Furniture and equipment		763			669
Total property, plant and equipment		334,532			317,885
Accumulated depreciation, depletion and amortization		(167,174	)		(160,765	)
Total property, plant and equipment, net		167,358			157,120
OTHER ASSETS:
Restricted cash		76			1,074
Deferred charges, net		7,916			8,334
Drilling advances		2,320			2,251
Other assets		150			150
Total other assets		10,462			11,809
TOTAL ASSETS	$	268,285		$	261,750
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	11,233		$	12,001
Revenue payable		7,728			6,770
Accrued interest		4,790			1,534
Accrued drilling and operating costs		2,048			2,810
Commodity derivative contracts		5,422			480
Other accrued liabilities		4,306			4,831
Due to related parties		1,865			979
Total current liabilities		37,392			29,405
LONG-TERM LIABILITIES:
Long-term debt		132,715			132,685
Asset retirement obligation		4,473			4,391
Commodity derivative contracts		545			—
Total long-term liabilities		137,733			137,076
COMMITMENTS AND CONTINGENCIES (Footnote 12)
SHAREHOLDERS’ EQUITY:
Common stock, no par value, unlimited shares authorized, 208,204,570 and 208,194,570 common shares issued and outstanding at March 31, 2008 and December 31, 2007, respectively		249,980			249,980
Additional paid-in capital		15,222			14,366
Accumulated other comprehensive loss – fair value of commodity hedging		(4,554	)		(480	)
Accumulated other comprehensive loss – foreign exchange		(7	)		(29	)
Accumulated deficit		(167,481	)		(168,568	)
Total shareholders’ equity		93,160			95,269
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	268,285		$	261,750

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

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GASTAR EXPLORATION LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

	For the Three Months Ended March 31,
	2008			2007
	(in thousands, except shares and per share data)
REVENUES:
Natural gas and oil revenues	$	16,846		$	7,515
Unrealized natural gas hedge loss		(1,413	)		—
Total revenues		15,433			7,515
EXPENSES:
Production taxes		269			294
Lease operating expenses		1,542			1,695
Transportation and treating		459			323
Depreciation, depletion and amortization		6,409			4,341
Accretion of asset retirement obligation		82			66
Mineral resource properties		—			13
General and administrative expenses		4,275			6,792
Litigation settlement expense		—			1,365
Total expenses		13,036			14,889
INCOME (LOSS) FROM OPERATIONS		2,397			(7,374	)
OTHER (EXPENSES) INCOME:
Interest expense		(2,096	)		(3,943	)
Investment income and other		823			363
Foreign transaction loss		(37	)		(1	)
INCOME (LOSS) BEFORE INCOME TAXES		1,087			(10,955	)
Provision for income taxes		—			—
NET INCOME (LOSS)	$	1,087		$	(10,955	)
NET INCOME (LOSS) PER SHARE:
Basic and diluted	$	0.01		$	(0.06	)
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
Basic and diluted		207,098,570			195,015,561

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

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GASTAR EXPLORATION LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	For the Three Months Ended March 31,
	2008			2007
	(in thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$	1,087		$	(10,955	)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization		6,409			4,341
Stock based compensation		856			1,236
Unrealized natural gas hedge loss		1,413			—
Amortization of deferred financing costs and debt discount		463			1,077
Accretion of asset retirement obligation		82			66
Changes in operating assets and liabilities:
Restricted cash for hedging program		1,000			—
Accounts receivable		(4,648	)		2,298
Prepaid expenses		118			321
Accounts payable and accrued liabilities		7,512			1,897
Net cash provided by operating activities		14,292			281
CASH FLOWS FROM INVESTING ACTIVITIES:
Development and purchases of natural gas and oil properties		(19,957	)		(18,389	)
Drilling advances		(1,132	)		—
Purchase of furniture and equipment		(94	)		(15	)
Net cash used in investing activities		(21,183	)		(18,404	)
CASH FLOWS FROM FINANCING ACTIVITIES:
Increase in restricted cash		(2	)		(1	)
Deferred financing charges and other		7			—
Net cash provided by (used in) financing activities		5			(1	)
NET DECREASE IN CASH AND CASH EQUIVALENTS		(6,886	)		(18,124	)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD		85,854			40,733
CASH AND CASH EQUIVALENTS, END OF PERIOD	$	78,968		$	22,609

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

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GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Summary of Significant Accounting Policies

The accounting policies followed by Gastar Exploration Ltd. (the “Company”) are set forth in the notes to the Company’s audited condensed consolidated financial statements in its Annual Report on Form 10-K for the year ended December 31, 2007. Additionally, refer to the notes to those financial statements 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 accompanying interim condensed consolidated financial statements have not been audited by independent registered public accountants but, in the opinion of management, reflect all normal and recurring adjustments considered necessary for a fair presentation of the financial position and results of operations. The results of operations for the three months ended March 31, 2008 are not necessarily indicative of results to be expected for the full year.

The condensed consolidated financial statements of the Company are presented in United States (“U.S.”) dollars unless otherwise noted and have been prepared by management in accordance with accounting principles generally accepted in the United States of America (“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 its subsidiaries. The entities included in these consolidated accounts are all wholly owned. All significant intercompany accounts and transactions have been eliminated in consolidation.

Certain information provided for the prior period has been reclassified to conform to the presentation adopted in 2008.

New Accounting Pronouncements

Fair Value Measurements.In September 2006, the Financial Accounting Standards Board (“FASB”) issued SFAS 157, Fair Value Measurements (“SFAS 157”), which defines fair value, establishes a framework for measuring fair value, and expands disclosures about fair value measurements. SFAS 157 applies to other accounting pronouncements that require or permit fair value measurements; however, it does not require any new fair value measurements. The provisions of SFAS 157 are effective for the years beginning after November 15, 2007 and interim periods within those years. The FASB has also issued Staff Position FSP FAS No. 157-2 (“FSP FAS No. 157-2”), which delays the effective date of SFAS 157 for nonfinancial assets and liabilities, except for items that are recognized or disclosed at fair value in the financial statements on a recurring basis (at least annually), until fiscal years beginning after November 15, 2008. Effective January 1, 2008, the Company adopted SFAS 157 and has chosen to defer the implementation of nonfinancial assets and liabilities in accordance with FSP FAS No. 157-2. The effect of adoption in January 1, 2008 was immaterial to the Company’s financial position. The adoption of FSP FAS No. 157-2 is not expected to have a material impact on the Company’s results of operations, cash flows or financial positions. See Note 10, “Fair Value Measurements” for additional information regarding the adoption of SFAS No. 157.

FASB Statement of Accounting Standard No. 159,“The Fair Value Option for Financial Assets and Financial Liabilities” (“SFAS No. 159”): SFAS No. 159, issued in February 2007, allows entities the option to measure eligible financial instruments at fair value as of specified dates. Such election, which may be applied on an instrument by instrument basis, is typically irrevocable once elected. SFAS No. 159 is effective for fiscal years beginning after November 15, 2007, and early application is allowed under certain circumstances. The Company adopted SFAS 159 on January 1, 2008, which allows an entity the

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GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

irrevocable option to elect fair value for the initial and subsequent measurement for certain financial assets and liabilities on a contract-by-contract basis. The Company did not elect fair value as an alternative, as provided under SFAS 159 for any of its financial assets and liabilities that are not currently measured at fair value.

Non-controlling Interests in Consolidated Financial Statements.In December 2007, the FASB Issued SFAS No. 160, “Noncontrolling Interests in Consolidated Financial Statements, an amendment of Accounting Research Bulletin No. 51” (“SFAS No. 160”), which improves the relevance, comparability and transparency of the financial information that a reporting entity provides in its consolidated financial statements by establishing accounting and reporting standards for the noncontrolling interest in a subsidiary and for the deconsolidation of a subsidiary. This statement is effective for fiscal years beginning after December 15, 2008. The Company does not expect the adoption of SFAS No. 160 to have a material impact on the Company’s consolidated financial position, results of operations or cash flows.

Business Combinations.In December 2007, FASB issued SFAS No. 141 (revised 2007), “Business Combinations” (“SFAS No. 141R”), which replaces SFAS No. 141 (“SFAS No. 141”). This statement retains the fundamental requirements in SFAS No. 141 that the acquisition method of accounting (which SFAS No. 141 called thepurchase method) be used for all business combinations. SFAS No. 141R also establishes principles and requirements for how the acquirer: (a) recognizes and measures in its financial statements the identifiable assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree; (b) recognizes and measures the goodwill acquired in the business combination or a gain from a bargain purchase; and (c) determines what information to disclose to enable users of the financial statements to evaluate the nature and financial effects of the business combination. SFAS No. 141R is effective as of the beginning of an entity’s fiscal year that begins after December 15, 2008. Early adoption is prohibited. The Company is currently evaluating the impact of adopting SFAS No. 141R, which also requires acquisition transaction costs to be expensed as incurred rather than capitalized as a direct cost of the acquisition, as transaction costs are not considered an element of the fair value of the company acquired. Depending upon the size, nature and complexity of a future acquisition transaction, such transaction costs could be material to the Company’s results of operations.

2. 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 states of California, Montana, Texas, West Virginia and Wyoming in the United States and in New South Wales and Victoria in Australia. The following schedule represents natural gas and oil property costs by country:

	United States			Australia			Total
	(in thousands)
From inception to March 31, 2008:
Natural gas and oil properties, full cost method of accounting:
Unproved properties	$	59,562		$	24,717		$	84,279
Proved properties		248,886			604			249,490
Total natural gas and oil properties		308,448			25,321			333,769
Furniture and equipment		666			97			763
Total property and equipment		309,114			25,418			334,532
Impairment of proved natural gas and oil properties		(104,205	)		(604	)		(104,809	)
Accumulated depreciation, depletion and amortization		(62,350	)		(15	)		(62,365	)
Total accumulated depreciation, depletion and amortization		(166,555	)		(619	)		(167,174	)
Total property and equipment, net	$	142,559		$	24,799		$	167,358

At March 31, 2008, unproved properties not being amortized consisted of U.S. drilling in progress costs of $9.9 million, U.S. acreage acquisition costs of $49.7 million and Australian unevaluated property costs of $24.7 million.

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GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

There was no impairment of United States or Australian properties during the three months ended March 31, 2008 or 2007.

3. Long-Term-Debt

The following shows the Company’s long-term debt as of the dates indicated:

	March 31, 2008		December 31, 2007
	(in thousands)
Revolving credit facility	$	—	$	—
12 3/4% senior secured notes		99,524		99,506
Convertible senior debenture		30,000		30,000
Subordinated unsecured notes payable		3,191		3,179
Total net carrying value of long-term debt		132,715		132,685
Debt discount costs to be accreted		535		565
Total long-term debt at maturity	$	133,250	$	133,250

12 ³/4% Senior Secured Notes due 2012

On November 29, 2007, Gastar Exploration USA, Inc. (“Gastar USA”), a wholly owned subsidiary of Gastar Exploration Ltd., (“Parent”) sold $100.0 million aggregate principal amount of 12 ³/4% Senior Secured Notes due December 1, 2012 (“12 ³/4% Senior Secured Notes”) at an issue price of 99.50%. Approximately $76.7 million of the $92.5 million net proceeds from the offering were used to repay the then outstanding senior secured notes, with the remaining net proceeds to be used for general corporate purposes. Interest is payable, semi-annually on June 1 and December 1, in cash on the principal amount at an annual rate of 12 ³/4%. The annual effective interest rate, after amortization of the debt discount and fees paid to establish the 12 ³/4% Senior Secured Notes, is 14.89%. The 12 ³/4% Senior Secured Notes are fully and unconditionally guaranteed jointly and severally by Gastar USA, the Parent and all of the Parent’s existing and future material domestic subsidiaries. The 12 ³/4% Senior Secured Notes and the guarantees are secured by a lien on Gastar USA’s principal domestic oil and gas properties and other assets that secure Gastar USA’s revolving credit facility (“Revolving Credit Facility”), subject to certain exceptions. The 12 ³/4% Senior Secured Notes mature on December 1, 2012.

As of March 31, 2008, the Company was in compliance with all debt covenants under the 12 ³/4% Senior Secured Notes.

Revolving Credit Facility

On November 29, 2007, concurrent with the closing of the 12 ³/4% Senior Secured Notes, Gastar USA entered into a revolving credit facility currently providing for a first priority lien maximum borrowing base of $19.4 million. At March 31, 2008, $2.5 million of the available borrowing base was utilized as collateral for a $2.5 million letter of credit to support the Company’s hedging activities. The balance of the borrowing base, or $16.9 million, remained available to the Company. The borrowing base is to be redetermined at least semiannually, using the lender’s usual and customary criteria for natural gas and oil reserve valuation. The applicable interest rate margin varies from -0.75% to 0.0% in the case of borrowings based on the prime rate and from 1.5% to 2.25% in the case of borrowings based on the Eurodollar rate, depending on the utilization level in relation to the borrowing base. At March 31, 2008, the prime rate and the Eurodollar rate were 5.25% and 2.7%, respectively. 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, excluding de minimus value properties as determined by the lender. The revolving credit facility matures on October 15, 2009.

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GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

As of March 31, 2008, the Company was in compliance with all debt covenants under the revolving credit facility.

Convertible Senior Debentures

In November 2004, the Company issued $30.0 million aggregate principal amount of convertible senior unsecured debentures. The convertible senior debentures have a term of five years and will be due November 20, 2009 and bear interest at 9.75% per annum, payable quarterly. The convertible senior debentures are convertible by the holders into 6,849,315 common shares at a conversion price of $4.38 per share

Subordinated Unsecured Notes Payable

The Company’s subordinated unsecured notes mature between April 2009 and September 2009, bear interest at 10% per annum and are callable by the Company at 105% after three years and 101% after four years.

4. Equity Compensation Plans

Share-Based Compensation Plans

2002 Stock Option Plan. The Company’s 2002 Stock Option Plan was approved and ratified by the Company’s shareholders in July 2002. It authorizes the Company’s Board of Directors to issue stock options to directors, officers, employees and consultants of the Company and its subsidiaries to purchase a maximum of 25.0 million common shares. Stock option grant expirations vary between five and ten years. The vesting schedule has varied from two years to four years but generally has occurred over a four-year period at 25% per year beginning on the first anniversary date of the grant. Stock options issued pursuant to the Company’s 2002 Stock Option Plan have an exercise price determined by the Board of Directors, but that exercise price cannot be less than the market price on the date immediately prior to the date of grant as reported by any stock exchange on which the Company’s common shares are listed. If a stock option granted under the Company’s 2002 Stock Option Plan expires or terminates for any reason in accordance with the terms of the Company’s Stock Option Plan, the unpurchased common shares subject to that stock option become available for other stock option grants.

In April 2004, the Board of Directors amended the provisions of the Company’s 2002 Stock Option Plan to specifically incorporate a provision to provide for stock options to be exercised on a cashless basis, whereby the Company issues to the optionee the number of common shares equal to the stock option exercised, less the number of common shares which when multiplied by the market price at the date of exercise equals the aggregate exercise price for all of the common shares exercised. As of March 31, 2008, stock option grants covering the issuance of 9,648,750 common shares were outstanding under the 2002 Stock Option Plan.

2006 Gastar Long-Term Stock Incentive Plan.On June 1, 2006, the Company’s shareholders approved the 2006 Gastar Long-Term Stock Incentive Plan. The 2006 Gastar Long-Term Stock Incentive Plan authorizes the Company’s Board of Directors to issue stock options, stock appreciation rights, bonus stock awards and any other type of award established by the Remuneration Committee which is consistent with the Plan’s purposes to directors, officers and employees of the Company and its subsidiaries covering a maximum of 5.0 million common shares. The contractual life and vesting period for a grant is determined by the Board of Directors at the time the grant is awarded. The vesting period for restricted common stock grants during 2007 and 2008 was over four years, with one-third vesting on the second, third and fourth anniversaries of the date of grant. As of March 31, 2008, grants covering the issuance of 1,106,000 restricted common shares were outstanding under the 2006 Gastar Long-Term Stock Incentive Plan.

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GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Determining Fair Value under SFAS No. 123R

In determining fair value for stock option grants pursuant to SFAS No. 123R, the Company utilized the following assumptions:

Valuation and Amortization Method. The Company estimates the fair value of share-based awards granted using the Black-Scholes-Merton valuation model. The fair value of all awards is expensed using the “graded-vesting method”.

Expected Life.The expected life of awards granted represents the period of time that stock options are expected to be outstanding. Prior to 2008, the Company determined the expected life using the “simplified method” resulting in a 6.25-year expected life in accordance with Staff Accounting Bulletin No. 107 for all stock options issued with a four-year vesting period and a ten-year grant expiration. Using the simplified method, stock options that have been issued with two and three-year vesting periods and having a ten-year expiration have an expected life of 5.75 and 6.0 years, respectively. Beginning in 2008, management determined the expected life of stock option grants to be 6.25 years, based on historical records.

Expected Volatility. Using the Black-Scholes-Merton valuation model, the Company estimates the volatility of its common shares at the beginning of the quarter in which the stock option is granted. The volatility is based on historical movements of our common share price on the American Stock Exchange and the Toronto Stock Exchange over a period that approximates the expected life.

Risk-Free Interest Rate. The Company utilizes a risk-free interest rate equal to the rate of U.S. Treasury zero-coupon issues as of the date of grant with a term equivalent to the stock option’s expected life.

Expected Dividend Yield. The Company has not paid any cash dividends on its common shares and does not anticipate paying any cash dividends in the foreseeable future. Consequently, a dividend yield of zero is utilized in the Black-Scholes-Merton valuation model.

Expected Forfeitures. Beginning March 1, 2008, the Company increased the forfeiture rate to 6% from 5% previously used. The forfeiture rate is used in calculating compensation expense and is based on the number of forfeitures of all unvested stock option since January 1, 2004 as a percentage of all stock option grants since January 1, 2004 calculated at the beginning of the year.

The fair value of each stock option grant is estimated on the date of grant using the Black-Scholes-Merton valuation pricing model. There were no stock options granted during the three months ended March 31, 2008. The table below summarizes the number of stock options granted and the assumptions for the stock options granted for the period indicated.

	For the Three Months Ended March 31, 2007
Stock options granted	227,000
Expected life (years)	6.25
Expected volatility	44.4%
Risk-free interest rate	4.6%-4.8%

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GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

The weighted average grant date fair value of stock options granted and the intrinsic value of stock options exercised are shown below for the periods indicated. Intrinsic value of stock options is calculated using the difference between the common share price on the date of exercise and the exercise price times the number of stock options exercised. There were no stock options granted or exercised during the three months ended March 31, 2008.

	For the Three Months Ended March 31, 2007
Weighted average fair value per share of stock options granted	$	1.08
Intrinsic value of stock options exercised	$	—

Stock Option Activity

The following table summarizes the annual changes and option exercise prices for stock options under the Company’s Stock Option Plan for the three months ended March 31, 2008:

	Number of Shares Under Stock Options	Weighted Average Exercise Price
Stock options outstanding as of December 31, 2007	10,173,750	$	3.19
Stock options granted	—	$	—
Stock options exercised	—	$	—
Stock options cancelled/expired	525,000	$	4.27
Stock options outstanding as of March 31, 2008	9,648,750	$	3.14
Stock options exercisable:
March 31, 2008	5,643,866	$	3.21

The table below summarizes certain information about the stock options for the three months ended March 31, 2008. Fair value calculations are as of the date of grant.

	Number of Shares Under Stock Options	Weighted Average Fair Value
Unvested stock options at the beginning of the quarter	5,045,834	$	1.22
Unvested stock options at the end of the quarter	4,578,334	$	1.21
Stock options granted during the quarter	—	$	—
Stock options vested during the quarter	117,500	$	1.68
Stock options forfeited/canceled during the quarter	525,000	$	1.09

As of March 31, 2008, there was no aggregate intrinsic value for outstanding stock options, and the remaining weighted average contractual life of outstanding stock options was 5.0 years. As of March 31, 2008, there was no aggregate intrinsic value for exercisable stock options, and the remaining weighted average contractual life of exercisable stock options was 3.5 years. As of March 31, 2008, the total fair value of exercisable stock options was $5.6 million.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Restricted Share Activities

The following table summarizes the changes and grant date prices for restricted common share grants for the three months ended March 31, 2008:

	Number of Shares Under Stock Options	Weighted Average Grant Date Fair Value
Restricted common shares outstanding as of December 31, 2007	1,096,000	$	2.15
Restricted common shares granted	10,000	$	1.09
Restricted common shares vested	—	$	—
Restricted common shares cancelled/expired	—	$	—
Restricted common shares outstanding as of March 31, 2008	1,106,000	$	2.14

The following table summarizes the range of grant dates (expiration dates) and grant date prices for restricted common shares outstanding and unvested as of March 31, 2008:

	Restricted Common Shares Outstanding	Grant Date Fair Value
July 3, 2007 (July 3, 2011)	983,500	$	2.20
August 27, 2007 (August 27, 2011)	112,500	$	1.67
January 16, 2008 (January 16, 2012)	10,000	$	1.09
Total	1,106,000	$	2.14

Stock-Based Compensation Expense

For the three months ended March 31, 2008 and 2007, the Company recorded stock-based compensation expense for stock options and restricted common shares granted using the fair-value method of $856,000 million and $1.2 million, respectively. All stock based compensation costs were expensed and not tax effected, as the Company currently records no income tax expense. All common shares issued upon exercise or vesting are reserved and non-assessable.

5. Commodity Hedging Contracts

The following costless collar transactions were outstanding with associated notional volumes and contracted floor and ceiling prices that represent hedge prices for the index specified as of March 31, 2008:

Date	Period	Derivative Instrument (1)	Hedge Strategy	Notional Daily Volume	Total of Notional Volume	Floor Price		Ceiling Price		Index		Production Area Hedged
				(MMBtu)	(MMBtu)	(MMBtu)		(MMBtu)
09/21/07	Cal 08	CC	Cash flow	2,000	732,000	$	5.50	$	7.50	CIG	(3)	WY
12/12/07	Cal 08	CC	Cash flow	5,000	1,830,000	$	6.75	$	8.00	HSC	(2)	TX
01/03/08	02-12/08	CC	Cash flow	5,000	1,675,000	$	7.00	$	8.88	HSC	(2)	TX
01/18/08	02-12/08	CC	Cash flow	800	268,000	$	6.00	$	7.90	CIG	(3)	WY
02/19/08	Cal 09	CC	Cash flow	5,000	1,825,000	$	8.00	$	9.30	HSC	(2)	TX

(1) Costless collars.

(2) East-Houston-Katy - Houston Ship Channel.

(3) Inside FERC Colorado Interstate Gas, Rocky Mountains.

As of March 31, 2008, the Company’s current cash flow hedge positions were with counterparties that are major United States financial institutions. The credit support for certain of the Company’s hedges is a $2.5 million letter of credit, with the remaining credit support under the Revolving Credit Facility through intercreditor agreements. Based on the Company’s December 31, 2007 third party engineering report, the Company had approximately 50% of its 2008 estimated proved developed production hedged and 30% of its 2009 estimated proved developed production hedged.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

The Company recorded a short term and a long term derivative liability of $5.4 million and $545,000, respectively, related to the difference between hedged commodity prices and market prices on hedged volumes as of March 31, 2008, after application of FAS157 Fair Value Measurement. All of the Company’s derivative instruments have been designated cash flow as hedging instruments and are deemed to be highly effective. The Company recognized unrealized losses in the statement of operations on the cash flow hedges due to ineffectiveness of $169,000 and $1.2 million related to the time value of the costless collars. The Company records time value on the costless collars designated as cash flow hedges currently in earnings, as it has elected to exclude time value from its assessment of hedge effectiveness.

6. Common Shares

Authorized

The Company’s articles of incorporation allow the Company to issue an unlimited number of common shares without par value.

Other Share Issuances

During three months ended March 31, 2008, pursuant to the Company’s 2006 Gastar Long-Term Stock Incentive Plan, the Company issued 10,000 restricted common shares to an employee, subject to vesting.

Shares Reserved

At March 31, 2008, the Company has reserved 16,730,586 common shares to be issued pursuant to the conversion of convertible debt (6,849,315 common shares), exercise of options (9,648,750 common shares) and the exercise of warrants (232,521 common shares).

7. Warrants

The following table summarizes warrant information to purchase common shares as of March 31, 2008:

	Number of Warrants	Fair Value of Warrants (in thousands)		Weighted Average Warrant Price		Weighted Average Remaining Life in Years	Weighted Average Exercise Price
Warrants issued in connection with $3.25 million subordinated unsecured notes payable	232,521	$	235	$	2.80	1.1	$	2.80

8. Interest Expense

The following tables summarize the components of interest expense:

	For the Three Months Ended March 31.
	2008			2007
	(in thousands)
Interest expense:
Cash and accrued	$	4,004		$	2,866
Amortization of deferred financing costs and debt discount		463			1,077
Capitalized interest		(2,371	)		—
Total interest expense	$	2,096		$	3,943

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(Unaudited)

9. Income Taxes

Due to the Company’s significant net operating loss carryforwards, the Company did not record any income tax expense for the three months ended March 31, 2008 and 2007. The Company fully reserves its deferred tax asset through a valuation allowance.

10. Fair Value Measurements

Fair Value Measurements.In September 2006, the FASB issued SFAS 157, which defines fair value, establishes a framework for measuring fair value, and expands disclosures about fair value measurements. SFAS 157 applies to other accounting pronouncements that require or permit fair value measurements; however, it does not require any new fair value measurements.

SFAS 157 establishes a valuation hierarchy for disclosure of the inputs to valuation used to measure fair value. This hierarchy prioritizes the inputs into three broad levels as follows.

• Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities.

• 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. 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 zero cost collars. Although the Company utilizes third party broker quotes to assess the reasonableness of prices and valuation techniques, the Company does not have sufficient corroborating market evidence to support classifying these assets and liabilities as Level 2.

A financial asset or liability’s classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The determination of the fair values below incorporates various factors required under SFAS 157, including the impact of our nonperformance risk on our liabilities. The following table provides the assets and liabilities carried at fair value measured on a recurring basis as of March 31, 2008:

	As of March 31, 2008
Recurring Fair Value Measures	Level 1		Level 2		Level 3			Total
	(in thousands)
Assets:
Derivative assets	$	—	$	—	$	—		$	—
Liabilities:
Derivative liabilities	$	—	$	—	$	(5,967	)	$	(5,967	)

The following table sets forth a reconciliation of changes in the fair value of financial assets and liabilities classified as level 3 in the fair value hierarchy:

	Derivatives
	(in thousands)
Balance as of January 1, 2008	$	(391	)
Total gains or losses (realized or unrealized)		—
Included in earnings (1)		(1,413	)
Included in other comprehensive loss		(4,395	)
Purchases, issuances and settlements		232
Transfers in and out of Level 3		—
Balance as of March 31, 2008	$	(5,967	)
Changes in unrealized losses relating to derivatives still held as of March 31, 2008	$	(1,413	)

(1) This amount is included in revenues on the statement of operations as unrealized gas hedge loss.

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(Unaudited)

11. Earnings or Loss per Share

In accordance with the provisions of Statement of Financial Standards No. 128 ‘Earnings per Share’, basic earnings or loss per share is computed on the basis of the weighted average number of common shares outstanding during the periods. 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. Diluted amounts are not included in the computation of diluted loss per share, as such would be anti-dilutive.

	For the Three Months Ended March 31,
	2008		2007
	(in thousands, except per share and share data)
Basic and diluted income (loss) and shares outstanding:
Net income (loss)	$	1,087	$	(10,955	)
Weighted average common shares outstanding:
Basic and diluted		207,098,570		195,015,561
Basic and diluted income (loss) per common share:
Basic and diluted	$	0.01	$	(0.06	)
Common shares excluded from denominator as anti-dilutive:
Stock options (1)		9,648,750		10,699,750
Unvested restricted common shares (2)		1,106,000		—
Warrants (1)		232,521		2,732,521
Convertible senior debentures (1)		6,849,315		6,849,315
Total		17,836,586		20,281,586

(1) Common shares for the 2008 period have been excluded as the strike price of each was greater than the market price as of March 31, 2008.

(2) Unvested common shares are included in the total outstanding number of common shares but are excluded from the calculation of weighted average common shares when calculating income per share.

12. Commitments and Contingencies

Litigation

The Company is party to various litigation matters. The ultimate outcome of the matters discussed below cannot presently be determined, nor can the liability that could potentially result from an adverse outcome be reasonably estimated at this time. The more significant litigation matters are summarized below.

Arbitration against GeoStar Corporation and Affiliates. On October 18, 2006, in connection with 10 wells to be drilled in Victoria, Australia on the jointly owned EL 4416 exploration license operated by GeoStar Corporation, the Company sent a letter to GeoStar demanding the arbitration of certain disputed issues and interpretations under a Participation and Operating Agreement (“POA”) with GeoStar and its subsidiaries. Among other items, the claims the Company presented for resolution in arbitration include claims relating to GeoStar’s demands for cash calls under the POA while simultaneously asserting that certain provisions of the POA, including overhead reimbursement rates, need to be renegotiated on terms that the Company believes are not reasonable or within industry standards. The Company has also requested that GeoStar’s Australian subsidiary provide a record title assignment of the Company’s beneficial interests in EL 4416, the exploration license in the Gippsland Basin property in Victoria, Australia. The Company has approximately $9.9 million invested in EL 4416 as of March 31, 2008. GeoStar contends that the Company is not entitled to the record title assignment notwithstanding the Company’s significant investment. The Company’s former Chairman of the Board is a major shareholder and President of GeoStar. GeoStar has voluntarily dismissed its efforts to enjoin the arbitration from

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(Unaudited)

proceeding and has answered and asserted counterclaims. Those counterclaims include (a) a request for a declaration that the Company has no rights to participate in brown coal projects in EL 4416, (b) a request for a declaration that the Company did not earn an interest under the POA as to certain wells the Company drilled in East Texas, (c) breach of contract for failure to pay certain bills and expenses and (d) breach of contract to pay for employee expenses and services. The Company, which denies and intends to vigorously defend each of these counterclaims, contends that it has participation rights to the full scope of EL 4416 under the terms of the POA and that the Texas wells were drilled on lands to which the Company obtained rights under separate 2005 Purchase and Sale Agreements. The three-member arbitration panel has been appointed. The date of the arbitration has been postponed and a new date has not been determined.

Gastar Exploration, Ltd., Gastar Exploration Texas, Inc., f/k/a First Texas Development, Inc., Gastar Exploration Texas LLC, f/k/a Bossier Basin, LLC, and Gastar Exploration Texas LP, f/k/a First Source Gas, LP v. GeoStar Corporation, First Source Texas, Inc., First Source Bossier, LLC, and First Texas Gas, LP. In July 2007, the Company filed a lawsuit in Robertson County, Texas against GeoStar and affiliates seeking relief in connection with the failure by GeoStar and its affiliates to execute formal assignments of certain leases that were omitted from the schedule of leases attached to the assignments executed by GeoStar affiliates in June 2005 pursuant to Purchase and Sale Agreements covering Texas properties of GeoStar and its affiliates. The lawsuit asks the court to decree that in the transaction evidenced by the Purchase and Sale Agreements, affiliates of the Company acquired title to all properties in Texas in which GeoStar and its affiliates owned an interest and that GeoStar and its affiliates are obligated to execute formal assignments with regard to all such leases. GeoStar and one of its affiliates have filed a challenge to the Texas court’s jurisdiction. Additionally, GeoStar and certain of its affiliates have also filed counterclaims in this litigation, which are described below and in the section below entitled “GeoStar Look Back Developments”.

Gastar Exploration Ltd., Gastar Exploration USA, Inc. f/k/a First Sourcenergy Wyoming Inc., Gastar Exploration New South Wales, Inc., f/k/a First Sourcenergy Group, 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, and Gastar Exploration Texas LP, f/k/a First Source Gas, LP v. GeoStar Corporation. In July 2007, the Company and affiliates filed a lawsuit in the District Court of Harris County, Texas against GeoStar in connection with GeoStar’s failure to deliver to the Company and its affiliates the corporate records of the Company and to its affiliates that have been retained by GeoStar. Representatives of the Company and its affiliates previously demanded return of the corporate records retained by GeoStar, but GeoStar failed to return the records. The lawsuit asks the court to decree that the Company and its affiliates are entitled to possession of the corporate records and order their return to the Company and its affiliates. The lawsuit also seeks recovery of actual and punitive damages, costs, and attorney’s fees. GeoStar has now delivered some of the requested records that are the subject of this litigation to the Company, and the Company has requested that GeoStar deliver additional records. Additionally, GeoStar and certain of its affiliates have also filed counterclaims in this litigation, which are described below and in the section below entitled “GeoStar Look Back Developments”.

Gastar Exploration, Ltd., Gastar Exploration Texas, Inc., f/k/a First Texas Development, Inc., Gastar Exploration Texas LLC, f/k/a Bossier Basin, LLC, and Gastar Exploration Texas LP, f/k/a First Source Gas, LP v. GeoStar Corporation, First Source Texas, Inc., First Source Bossier, LLC, and First Texas Gas, LP. In August 2007, the Company and certain affiliates filed a second lawsuit in Robertson County, Texas, seeking a declaratory judgment that the Company and its affiliates have complied with the Look-Back provisions of the Texas Purchase and Sale Agreements that are the subject of the other Robertson County, Texas lawsuit referenced above, that the Company and its affiliates have complied with the provisions of the Texas Purchase and Sale Agreements relating to the drilling of wells, and that GeoStar and its affiliates hold no farm-in interest in properties owned by the Company’s affiliates. GeoStar and one of its affiliates have filed a challenge to the Texas court’s jurisdiction. The defendants also have generally denied the allegations made in the lawsuit. Additionally, GeoStar and certain of its affiliates have also filed counterclaims in this litigation, which are described in the following paragraph and in the section below entitled “GeoStar Look Back Developments”.

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(Unaudited)

Although it previously contested jurisdiction in Texas, GeoStar (together with certain of its affiliates) has as of January and February 2008 asserted counterclaims in all three Texas lawsuits similar to claims GeoStar had previously asserted and dismissed in the Michigan lawsuit described below. The counterclaims relate to Texas properties that were the subject of Purchase and Sale Agreements entered into in 2005, under which the Company acquired the interests of GeoStar-affiliated entities in properties in Texas. Specifically, GeoStar claims that the Company breached the Purchase and Sale Agreements by failing to provide information in connection with contingent “Look Back” payments under provisions of the Purchase and Sale Agreements, and by failing to make payments allegedly due to GeoStar under the Look-Back provisions, arising out of alleged changes in reserves following the sale of the Texas properties in June 2005. Although requesting only damages in an unspecified amount, GeoStar contends in the counterclaim that it would have been entitled under the Purchase and Sale Agreements to approximately 1.7 billion shares of Gastar stock. GeoStar also claims that the Company failed to timely comply with provisions of the Purchase and Sale Agreements relating to the drilling of 20 wells on the properties conveyed under the Purchase and Sale Agreements and by failing to drill and test at least two wells in the Travis Peak formation in Texas, allegedly entitling GeoStar to unspecified damages related to a farm-in interest under which it was allegedly entitled to the right to drill, complete, and operate wells in the Travis Peak formation on certain acreage. The Company intends to vigorously defend the counterclaims. The Company has moved to abate the Harris County proceedings with respect the counterclaims in favor of the earlier-filed Robertson County proceedings. Certain information that may be relevant to this matter is set forth below in the section below entitled “GeoStar Look Back Developments”.

GeoStar Corporation and West Virginia Gas Corporation v. Gastar Exploration Ltd. and J. Russell Porter. On July 27, 2007, the Company was served with a lawsuit filed by GeoStar and one of its affiliates, West Virginia Gas Corporation, in federal court in Saginaw, Michigan. GeoStar asserted a broad range of claims against the Company and its current chief executive officer, J. Russell Porter.

GeoStar initially sought in the Michigan suit to enjoin the Company’s arbitration against GeoStar and its affiliates. GeoStar has now voluntarily dismissed that request with prejudice.

GeoStar also claims in the Michigan suit that the POA was cancelled effective January 1, 2005, and that the parties have operated under oral contracts since that date. GeoStar asserts that the Company has breached the alleged oral contracts by allegedly failing to pay joint interest billings, authorizations for expenditures, and cash calls relating to operations or proposed operations on EL 4416 in Australia and West Virginia properties, in an unspecified amount exceeding $75,000. GeoStar also claims that the Company has breached alleged agreements to reimburse GeoStar for various payments and services allegedly performed by GeoStar and its personnel and paid on behalf of the Company by GeoStar. GeoStar claims that the amounts of the payments and the value of the services exceed $10.0 million. GeoStar alternatively alleges that if there was no contract covering those payments and services, it allegedly is entitled to reimbursement on equitable principles. On January 15, 2008, the federal court granted the Company’s motion to dismiss these claims for failure to state a claim on which relief could be granted. GeoStar filed a motion asking that the Court reconsider that ruling or permit it to replead the claims. On February 8, 2008, the federal court denied the motion to reconsider but granted GeoStar permission to replead those claims, which it did on February 22, 2008. In repleading those claims, GeoStar has restated the prior claims for oral agreement to reimburse certain expenses or equitable entitlement to reimbursement of certain expenses, and it specifies a number of items for which GeoStar is allegedly entitled to reimbursement from the Company. Pursuant to these claims, which are substantially duplicated by certain of the counterclaims GeoStar pursues in the arbitration, GeoStar seeks approximately $17.0 million. The Company filed a response to these claims on March 7, 2008.

GeoStar also asserted claims in the Michigan lawsuit relating to Texas properties that were the subject of Purchase and Sale Agreements entered into in 2005. GeoStar has voluntarily dismissed those claims without prejudice from the Michigan lawsuit and re-asserted similar claims in pending litigation in Harris and Robertson Counties, Texas, as discussed above and below under “GeoStar Look Back Developments.”

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(Unaudited)

West Virginia Gas Corporation (WVGC), an affiliate of GeoStar, also asserts claims against the Company’s current chief executive officer, alleging that the Company and its current chief executive officer tortiously interfered with an alleged contract between WVGC and certain West Virginia individuals and entities. According to the lawsuit, these individuals and entities allegedly promised to give their oil, gas, and coalbed methane opportunities in West Virginia and Pennsylvania to WVGC. WVGC alleged that Gastar and its chief executive officer caused those individuals and entities to establish and use new business entities to allegedly conceal opportunities from West Virginia Gas Corporation and to funnel them to the Company, the Company’s chief executive officer and the West Virginia individuals and entities. On January 15, 2008, the federal court dismissed these claims to the extent they were brought by GeoStar and to the extent they were brought against the Company. The court denied our chief executive’s motions to dismiss WVGC’s claim and a motion to reconsider that denial. Our chief executive intends to vigorously defend the claim.

GeoStar Look Back Developments. The Purchase and Sale Agreements between GeoStar and the Company relating to certain East Texas properties acquired by the Company in 2005 (the “PSAs”) contain a “Look Back” provision that is the subject of claims in three of the previously described lawsuits with GeoStar. Under the 2005 PSAs, GeoStar conveyed interests in certain Texas properties to the Company and was paid an agreed $43.5 million in consideration for the properties (including cash, 8.6 million shares of Company common stock and promissory notes), subject to certain purchase price adjustments relating to the period prior to closing. The interests conveyed by the PSAs comprise a portion of the security for the notes and the Guarantees.

Under the Look Back provision, two Look Back payments are to be calculated based in part on changes in proved and probable reserves attributable to certain of the Company’s leasehold interests over certain periods of time ending June 30, 2006 and 2007. If a Look Back payment is due to GeoStar under the PSAs, the PSAs require the payment to be effected through the issuance of the Company’s stock.

The PSAs provide that the calculation of the Look Back payment shall be based upon reserve estimates reported by Netherland Sewell & Associates, Inc. (“NSA”), or in certain circumstances, based upon an average of the NSA estimates and estimates obtained by GeoStar from an independent, professionally certified reservoir engineering firm utilizing the same regulatory requirements and reserve calculation guidelines as those employed by NSA in its estimates. Based on the NSA reserves estimate and the Look Back calculations set forth in the PSAs, the Company believes that no additional issuance of Company common shares is due GeoStar under the Look Back provision.

On November 1, 2007, GeoStar informed the board of directors of our Parent that it intended to submit a reserve report for purposes of the June 30, 2006 and 2007 Look Back analyses showing that the gross reserves attributable to the Company’s leasehold interests are substantially greater than those reflected in the NSA reserve reports on which the Company’s Look Back analyses were based. On November 7, 2007, GeoStar submitted a reserve report to the Company that reported a substantially greater reserve estimate than the estimates in the NSA reserve report.

On November 14, 2007, the Company received a reserve report of T.J. Smith & Company, Inc. (“T.J. Smith”) as well as a demand letter from GeoStar’s counsel (the “Demand Letter”) in which GeoStar asserted a purported right under the PSAs to receive additional shares of Gastar stock as a Look Back payment. In the Demand Letter, GeoStar asserts that T.J. Smith has estimated that the total proved and probable reserves in the Company’s Texas properties attributable to 100% of the working interest amount to 2.15 trillion cubic feet of gas, a number which is approximately fourteen times more than the proved and probable reserves estimated by NSA, the engineering firm selected by the parties in the PSAs. On the basis of that reserves estimate, GeoStar asserts in the Demand Letter that it is entitled to a Look Back payment of approximately 1.7 billion shares of Gastar stock, which if issued would constitute approximately 89% of the Company’s common equity and would result in a change in control of the Company under the Company’s debt agreements. In the Demand Letter, GeoStar further asserts that if its demand is not met, it will pursue remedies that may include reclaiming operatorship over certain of the Company’s Texas

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(Unaudited)

properties, rescission of the PSAs resulting in return of the properties covered by the PSAs and consideration paid, and unspecified injunctive relief. The Company does not believe that GeoStar is entitled to these remedies.

The Company believes that GeoStar’s assertions are without merit. The Company believes that the T.J. Smith reserve report was submitted in bad faith and does not meet the requirements of the PSAs because, among other things, it does not follow the same regulatory requirements and reserve calculation guidelines as those employed by NSA, as required by the terms of the PSAs. In addition, GeoStar has asserted that the Look Back analysis should be based on changes in reserves attributable to the entirety, or 8/8ths, of the Company’s leasehold interests with respect to its Texas properties, rather than on changes in reserves attributable to GeoStar’s net revenue interest in those properties as of the effectiveness of the PSAs, as the Company believes. The Company is pursuing discovery of data pertinent to the T.J. Smith report and GeoStar’s contentions relating thereto and will continue to evaluate the Company’s legal positions and options based on such discovery.

The Company intends to vigorously defend itself against GeoStar’s assertions. However, an unfavorable outcome in litigation relating to the Look Back could have a material adverse effect on the Company were GeoStar to obtain issuance of the requested shares and obtain control of the Company, rescission of the PSAs, or other relief to which it asserted it was entitled in the November demand letter. A change in control of the Company as a result of an issuance of shares to GeoStar may require the Company to refinance substantially all of its indebtedness under its existing debt agreements, which refinancing may not be obtainable or may not be on terms as favorable as under current debt agreements. Although the Company does not currently anticipate the need to access the equity capital markets through 2008 or early 2009 to continue its business plan, until these issues are resolved in whole or in significant part, it will be difficult for the Company to raise capital through the sale of equity.

In 2007, the Company recorded a $1.4 million litigation settlement expense accrual related to a proposed settlement with GeoStar regarding the various GeoStar arbitration and litigation matters. The settlement proposal was never finalized. At March 31, 2008, the Company had a receivable from GeoStar of approximately $3.7 million that was fully reserved due to the various litigation matters.

Other Litigation

The Company does not expect that the outcome of these proceedings will have a material adverse effect on its financial position, results of operations or cash flow.

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, Texas 12th 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, 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 and rendering judgment in favor of Navasota on all counts. The Company and Chesapeake filed a motion for rehearing on February 6, 2008, and if unsuccessful, will consider filing a petition for review to the Texas Supreme Court. Pursuant to an agreement between the Company and Chesapeake, any adverse result in this matter should impact only Chesapeake’s assigned leasehold interests. While this matter 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.

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(Unaudited)

Gastar Exploration Texas LP v. John E. McFarlane, et al (Cause No. 0-06-161) 87th Judicial District Court of Leon County, Texas. This suit is to quiet title to an undivided 25% mineral interest under an oil and gas lease dated December 4, 2003, covering approximately 2,598 gross acres (the “Lease”). John E. McFarlane and certain other family members contend that an undivided 25% mineral interest in the lands covered by the Lease are owned in trust by the grandchildren of Fay W. McFarlane and are not covered by the Lease as Gastar claims. McFarlane,et. al., filed an answer to the Company’s petition and also filed several different motions for summary judgment which were denied by the District Court. A day long mediation of this lawsuit occurred on August 24, 2007, but the parties were unable to settle this matter at that time. The lawsuit is in the discovery phase, and is currently set for a non-jury trial in October 2008. The existence of unleased mineral interests in this Lease could adversely impact the future development of the Lease. The Company will continue to vigorously pursue this claim.

Spencer D. Plummer, III v. GeoStar Corporation, Classic Star LLC, Gastar Exploration, Ltd., Thom Robinson, Tony Ferguson, and John W. Parrott; In the United States District Court of Utah, Central Division (Case No. 2:07-CV-00409). This lawsuit was filed on May 24, 2007 initially in Utah state court by Spencer Plummer, or the Plaintiff, in which he asserts breaches of his Employment Agreement and subsequent Termination Agreement (the “Agreements”) with his employer, Classic Star, a subsidiary of GeoStar. The Plaintiff claims that he has not received benefits promised under such Agreements, including 699,249 shares of Company stock. The Company is not a party to the Agreements on which Plaintiff’s claims are expressly based; however, the Company and Plaintiff are parties to a Stock Option Agreement on which Plaintiff claim to Company stock is partially based. The Company filed an Answer and Motion to Dismiss for lack of personal jurisdiction in Utah and for Plaintiff’s failure to state a claim upon which relief can be granted. Plaintiff filed a Motion to Remand to state court, and on September 5, 2007, the Court denied Plaintiff’s Motion to Remand. Thereafter, the Company’s co-defendant, Classic Star LLC, moved to transfer and consolidate the case in a United States Judicial Panel on Multi District Litigation (“MDL Panel”) in Kentucky with other cases in which Classic Star LLC is a named defendant. On October 22, 2007, the MDL Panel granted the motion to transfer. The Company is awaiting the Kentucky court’s ruling on its Motion to Dismiss.

Commitments

In March 2008, the Company entered into formal agreements with ETC Texas Pipeline, Ltd. (“ETC”) for the gathering, treating, purchase and transportation of the Company’s natural gas production from Hilltop area of East Texas. These agreements are effective September 1, 2007 and have a term of 10 years. ETC currently provides us 50 MMcfd of treating capacity and 120 MMcfd of gathering capacity. The Company has the right to request ETC build, at their cost, up to 150 MMcfd of treating and gathering capacity during the term of the agreement, provided that the Company’s production equals 85% of the then existing treating and gathering capacity for a 30 day period. The Company may at any time elect to have its treating and gathering capacity increased subject to cost indemnifications to ETC. Additional treating and gathering capacity requests must be in at least 25 MMcfd and 5 MMcfd increments, respectively. In addition, the Company must furnish to ETC information that reasonably demonstrates that its projected production for the five years after expansion is sufficient to warrant the costs to create the expanded treating and gathering capacity. The incremental volume increases in treating and gathering capacity shall be subject to marginal increases in treating fees. Pursuant to the agreements, the Company has access up to 150 MMcfd of firm transportation on ETC’s system or the pipelines of its affiliates or subsidiaries from the tailgate of the treating facility to Katy Hub. The Company has the option to sell and ETC has the obligation to buy, up to 150 MMcfd of the Company’s Hilltop production at delivery points upstream of ETC’s gathering and treating facilities. The Company does not have an obligation to deliver to ETC volumes in excess of 150 MMcfd, but should ETC elect to purchase such excess volumes, purchases will be subject to the treating and gathering expansion terms set forth in the agreements.

18

GASTAR EXPLORATION LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Registration Obligation

On November 29, 2007, Gastar USA sold $100.0 million aggregate principal amount of 12 ³/4% Senior Secured Notes at an issue price of 99.50% in a private placement to qualified institutional. In connection with the sale Gastar Exploration USA, Inc., other Guarantors and the Company entered into a registration rights agreement. Pursuant to the registration rights agreement, the Company and the Guarantors agreed that they would (1) within 150 days after the date of original issue of the 12 ³/4% Senior Secured Notes file a registration statement with the SEC to exchange the 12 ³/4% Senior Secured Notes for new notes of the Company having terms substantially identical in all material respects to the notes (except that the new notes will not contain terms relating to transfer restrictions); (2) use their reasonable best efforts to cause the registration statement to be declared effective within 240 days after the issue date; (3) as soon as practicable after the effectiveness of the registration statement, offer the new notes to the holders of the notes in exchange for the notes; and (4) keep the exchange offer open for not less than 30 days (or longer if required by applicable law) after the date notice of the exchange offer is mailed to the holders of the notes. Under existing SEC interpretations, the new notes will be freely transferable by holders other than Company affiliates after the exchange offer without further registration. In the event Gastar USA fails to meet its registration obligations as set forth above, Gastar USA has agreed to pay liquidated damages to the holders of the 12 ³/4% Senior Secured Notes in the form of additional cash interest payments on the 12 ³/4% Senior Secured Notes equal to 0.25% per annum for the first 90-day period, increasing to a maximum of 0.50% per annum for each subsequent 90-day period. The Company filed a Registration Statement on Form S-4 on April 10, 2008, which has not yet become effective.

13. Statement of Cash Flows – Supplemental Information

The following is a summary of supplemental cash paid and non-cash transactions disclosed in the notes to the condensed consolidated financial statements:

	For the Three Months Ended March 31,
	2008			2007
	(in thousands)
Cash paid for interest	$	748		$	2,871
Non-cash transactions:
Non-cash capital expenditures excluded from accounts payable and accrued drilling costs	$	(4,467	)	$	4,248
Asset retirement obligation included in oil and gas properties	$	—		$	422
Drilling advances application	$	1,063		$	1,048
Common shares issued under senior secured notes	$	—		$	606

14. Issuer Subsidiaries Condensed Consolidating Financial Statements

The following tables present condensed consolidating balance sheets as of March 31, 2008 and December 31, 2007 and the related condensed consolidating statements of operations and condensed consolidating statements of cash flows for the three months ended March 31, 2008 and 2007 of Gastar Exploration Ltd. (“Parent”), Gastar Exploration USA, Inc. (“Issuer”) and Gastar Exploration Texas, Inc., Gastar Exploration Texas LP, Gastar Exploration Texas LLC, Gastar Exploration New South Wales, Inc., Gastar Exploration Victoria, Inc. and Gastar Power Pty Ltd., a minor non-guarantor subsidiary included in issuer subsidiaries, (collectively referred to as “Issuer Subsidiaries”). Each of the Parent and the Issuer Subsidiaries, except for Gastar Power Pty Ltd., have fully and unconditionally guaranteed, on a joint and severally basis, the $100.0 million 12 ³/4% Senior Secured Notes and the Revolving Credit Facility. During 2007, Parent intercompany receivables were reclassified to investment in subsidiary with Issuer and Issuer Subsidiaries. Prior to January 1, 2008, interest was not charged on intercompany receivables or payables. Total intercompany interest charged by Parent to Issuer during the three months ended March 31, 2008 was $12,000, which was eliminated in consolidation.

19

Condensed Consolidating Parent and Issuer Subsidiaries Balance Sheets

As of March 31, 2008

(Unaudited)

ASSETS

	Parent			Issuer			Issuer Subsidiaries			Reclassifications and Eliminations			Gastar Exploration Ltd. and Subsidiaries
	(in thousands)
CURRENT ASSETS:
Cash and cash equivalents	$	34		$	—		$	78,934		$	—		$	78,968
Accounts receivable, net		7			265			9,132			(635	)		8,769
Due from related parties		—			—			1,611			—			1,611
Prepaid expenses		252			—			865			—			1,117
Total current assets		293			265			90,542			(635	)		90,465
PROPERTY, PLANT AND EQUIPMENT:
Natural gas and oil properties, full cost method of accounting:
Unproved properties, not being amortized		—			4,036			80,243			—			84,279
Proved properties		8			43,925			205,557			—			249,490
Total natural gas and oil properties		8			47,961			285,800			—			333,769
Furniture and equipment		—			—			763			—			763
Total property, plant and equipment		8			47,961			286,563			—			334,532
Accumulated depreciation, depletion and amortization		(7	)		(42,828	)		(124,339	)		—			(167,174	)
Total property, plant and equipment, net		1			5,133			162,224			—			167,358
OTHER ASSETS:
Restricted cash		30			—			46			—			76
Deferred charges, net		802			7,114			—			—			7,916
Drilling advances		—			—			2,320			—			2,320
Intercompany receivable and investment in subsidiaries		130,350			220,315			—			(350,665	)		—
Other assets		—			100			50			—			150
Total other assets		131,182			227,529			2,416			(350,665	)		10,462
TOTAL ASSETS	$	131,476		$	232,927		$	255,182		$	(351,300	)	$	268,285
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	39		$	—		$	11,194		$	—		$	11,233
Revenue payable		—			—			7,728			—			7,728
Accrued interest		469			4,321			—			—			4,790
Accrued drilling and operating costs		—			350			1,698			—			2,048
Commodity derivative contracts		—			5,422			—			—			5,422
Other accrued liabilities		138			635			4,168			(635	)		4,306
Due to related parties		—			—			1,865			—			1,865
Total current liabilities		646			10,728			26,653			(635	)		37,392
LONG-TERM LIABILITIES:
Long-term debt		33,191			99,524			—			—			132,715
Asset retirement obligation		5			2,331			2,137			—			4,473
Commodity derivative contracts		—			545			—			—			545
Intercompany payable		—			2,379			34,458			(36,837	)		—
Total long-term liabilities		33,196			104,779			36,595			(36,837	)		137,733
TOTAL SHAREHOLDERS’ EQUITY		97,634			117,420			191,934			(313,828	)		93,160
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	131,476		$	232,927		$	255,182		$	(351,300	)	$	268,285
											��

20

Condensed Consolidating Parent and Issuer Subsidiaries Balance Sheets

As of December 31, 2007

ASSETS

	Parent			Issuer			Issuer Subsidiaries			Reclassifications and Eliminations			Gastar Exploration Ltd. and Subsidiaries
	(in thousands)
CURRENT ASSETS:
Cash and cash equivalents	$	73		$	—		$	85,781		$	—		$	85,854
Accounts receivable, net		10			265			5,188			(635	)		4,828
Due from related parties		—			—			904			—			904
Prepaid expenses		291			—			944			—			1,235
Total current assets		374			265			92,817			(635	)		92,821
PROPERTY, PLANT AND EQUIPMENT:
Natural gas and oil properties, full cost method of accounting:
Unproved properties, not being amortized		—			2,988			66,856			—			69,844
Proved properties		8			43,611			203,753			—			247,372
Total natural gas and oil properties		8			46,599			270,609			—			317,216
Furniture and equipment		—			—			669			—			669
Total property, plant and equipment		8			46,599			271,278			—			317,885
Accumulated depreciation, depletion and amortization		(7	)		(42,828	)		(117,930	)		—			(160,765	)
Total property, plant and equipment, net		1			3,771			153,348			—			157,120
OTHER ASSETS:
Restricted cash		1,029			—			45			—			1,074
Deferred charges, net		924			7,410			—			—			8,334
Drilling advances		—			—			2,251			—			2,251
Intercompany receivable and investment in subsidiaries		128,677			209,494			—			(338,171	)		—
Other assets		—			100			50			—			150
Total other assets		130,630			217,004			2,346			(338,171	)		11,809
TOTAL ASSETS	$	131,005		$	221,040		$	248,511		$	(338,806	)	$	261,750
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	47		$	—		$	11,954		$	—		$	12,001
Revenue payable		—			—			6,770			—			6,770
Accrued interest		401			1,133			—			—			1,534
Accrued drilling and operating costs		—			350			2,460			—			2,810
Commodity derivative contracts		—			480			—			—			480
Other accrued liabilities		244			586			4,636			(635	)		4,831
Due to related parties		—			—			979			—			979
Total current liabilities		692			2,549			26,799			(635	)		29,405
LONG-TERM LIABILITIES:
Long-term debt		33,179			99,506			—			—			132,685
Asset retirement obligation		5			2,289			2,097			—			4,391
Intercompany payable		589			1,615			26,668			(28,872	)		—
Total long-term liabilities		33,773			103,410			28,765			(28,872	)		137,076
TOTAL SHAREHOLDERS’ EQUITY		96,540			115,081			192,947			(309,299	)		95,269
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	131,005		$	221,040		$	248,511		$	(338,806	)	$	261,750

21

Condensed Consolidating Parent and Issuer Subsidiaries Statements of Operations

For the Three Months Ended March 31, 2008

(Unaudited)

	Parent			Issuer			Issuer Subsidiaries			Reclassifications and Eliminations			Gastar Exploration Ltd. and Subsidiaries
	(in thousands)
REVENUES:
Natural gas and oil revenues	$	1		$	3,134		$	13,711		$	—		$	16,846
Unrealized natural gas hedge loss		—			(216	)		(1,197	)		—			(1,413	)
Total revenues		1			2,918			12,514			—			15,433
EXPENSES:
Production taxes		—			348			(79	)		—			269
Lease operating expenses		—			704			838			—			1,542
Transportation and treating		—			459			—			—			459
Depreciation, depletion and amortization		—			—			6,409			—			6,409
Accretion of asset retirement obligation		—			40			42			—			82
General and administrative expenses		297			42			3,936			—			4,275
Total expenses		297			1,593			11,146			—			13,036
INCOME (LOSS) FROM OPERATIONS		(296	)		1,325			1,368			—			2,397
OTHER (EXPENSES) INCOME:
Interest expense		(944	)		(1,146	)		(6	)		—			(2,096	)
Investment income and other		21			(10	)		812			—			823
Equity earnings in subsidiaries		2,349			2,180			—			(4,529	)		—
Foreign transaction (loss) gain		(43	)		—			6			—			(37	)
INCOME BEFORE INCOME TAXES		1,087			2,349			2,180			(4,529	)		1,087
Provision for income taxes		—			—			—			—			—
NET INCOME	$	1,087		$	2,349		$	2,180		$	(4,529	)	$	1,087

22

Condensed Consolidating Parent and Issuer Subsidiaries Statements of Operations

For the Three Months Ended March 31, 2007

(Unaudited)

	Parent			Issuer			Issuer Subsidiaries			Reclassifications and Eliminations		Gastar Exploration Ltd. and Subsidiaries
	(in thousands)
REVENUES:
Natural gas and oil revenues	$	1		$	2,153		$	5,361		$	—	$	7,515
Unrealized natural gas hedge loss		—			—			—			—		—
Total revenues		1			2,153			5,361			—		7,515
EXPENSES:
Production taxes		—			234			60			—		294
Lease operating expenses		1			727			967			—		1,695
Transportation and treating		—			323			—			—		323
Depreciation, depletion and amortization		—			1,529			2,812			—		4,341
Accretion of asset retirement obligation		—			40			26			—		66
Mineral resource properties		—			—			13			—		13
General and administrative expenses		364			—			6,428			—		6,792
Litigation settlement expense		—			—			1,365			—		1,365
Total expenses		365			2,853			11,671			—		14,889
LOSS FROM OPERATIONS		(364	)		(700	)		(6,310	)		—		(7,374	)
OTHER (EXPENSES) INCOME:
Interest expense		(3,926	)		—			(17	)		—		(3,943	)
Investment income and other		—			—			363			—		363
Equity loss in subsidiaries		(6,663	)		(5,963	)		—			12,626		—
Foreign transaction (loss) gain		(2	)		—			1			—		(1	)
LOSS BEFORE INCOME TAXES		(10,955	)		(6,663	)		(5,963	)		12,626		(10,955	)
Provision for income taxes		—			—			—			—		—
NET LOSS	$	(10,955	)	$	(6,663	)	$	(5,963	)	$	12,626	$	(10,955	)

23

Condensed Consolidating Parent and Issuer Subsidiaries Statements of Cash Flows

For the Three Months Ended March 31, 2008

(Unaudited)

	Parent			Issuer			Issuer Subsidiaries			Reclassifications and Eliminations			Gastar Exploration Ltd. and Subsidiaries
	(in thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	1,087		$	2,349		$	2,180		$	(4,529	)	$	1,087
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation, depletion and amortization		—			—			6,409			—			6,409
Stock based compensation		—			—			856			—			856
Unrealized natural gas hedge loss		—			216			1,197			—			1,413
Amortization of deferred financing costs and debt discount		134			329			—			—			463
Accretion of asset retirement obligation		—			40			42			—			82
Equity in loss of issuer subsidiaries		(2,349	)		(2,180	)		—			4,529			—
Changes in operating assets and liabilities, exclusive of effects of acquisition:
Restricted cash for hedging program		1,000			—			—			—			1,000
Accounts receivable		3			—			(4,651	)		—			(4,648	)
Prepaid expenses		39			—			79			—			118
Accounts payable and accrued liabilities		(46	)		3,237			4,321			—			7,512
Net cash provided by (used in) operating activities		(132	)		3,991			10,433			—			14,292
CASH FLOWS FROM INVESTING ACTIVITIES:
Development and purchases of natural gas and oil properties		—			(1,362	)		(18,595	)		—			(19,957	)
Drilling advances		—			—			(1,132	)		—			(1,132	)
Purchase of furniture and equipment		—			—			(94	)		—			(94	)
Subsidiary equity investment repayments		—			(2,614	)		—			2,614			—
Net cash used in investing activities		—			(3,976	)		(19,821	)		2,614			(21,183	)
CASH FLOWS FROM FINANCING ACTIVITIES:
Subsidiary equity investment repayments		87			—			2,527			(2,614	)		—
Increase in restricted cash		(1	)		—			(1	)		—			(2	)
Deferred financing charges and other		7			(15	)		15			—			7
Net cash provided by (used in) financing activities		93			(15	)		2,541			(2,614	)		5
NET DECREASE IN CASH AND CASH EQUIVALENTS		(39	)		—			(6,847	)		—			(6,886	)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD		73			—			85,781			—			85,854
CASH AND CASH EQUIVALENTS, END OF PERIOD	$	34		$	—		$	78,934		$	—		$	78,968

24

Condensed Consolidating Parent and Issuer Subsidiaries Statements of Cash Flows

For the Three Months Ended March 31, 2007

(Unaudited)

	Parent			Issuer			Issuer Subsidiaries			Reclassifications and Eliminations			Gastar Exploration Ltd. and Subsidiaries
	(in thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(10,955	)	$	(6,663	)	$	(5,963	)	$	12,626		$	(10,955	)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Depreciation, depletion and amortization		—			1,529			2,812			—			4,341
Stock based compensation		—			—			1,236			—			1,236
Amortization of deferred financing costs and debt discount		1,077			—			—			—			1,077
Accretion of asset retirement obligation		—			40			26			—			66
Equity in loss of issuer subsidiaries		6,663			5,963			—			(12,626	)		—
Changes in operating assets and liabilities, exclusive of effects of acquisition:
Accounts receivable		(3	)		100			2,201			—			2,298
Prepaid expenses		90			135			96			—			321
Accounts payable and accrued liabilities		(79	)		—			1,976			—			1,897
Net cash provided by (used in) operating activities		(3,207	)		1,104			2,384			—			281
CASH FLOWS FROM INVESTING ACTIVITIES:
Development and purchases of natural gas and oil properties		(1	)		(2,464	)		(15,924	)		—			(18,389	)
Purchase of furniture and equipment		—			—			(15	)		—			(15	)
Subsidiary equity investment repayments		—			—			(4,637	)		4,637			—
Net cash used in investing activities		(1	)		(2,464	)		(20,576	)		4,637			(18,404	)
CASH FLOWS FROM FINANCING ACTIVITIES:
Subsidiary equity investment repayments		3,277			1,360			—			(4,637	)		—
Increase in restricted cash		—			—			(1	)		—			(1	)
Net cash provided by (used in) financing activities		3,277			1,360			(1	)		(4,637	)		(1	)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS		69			—			(18,193	)		—			(18,124	)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD		46			—			40,687			—			40,733
CASH AND CASH EQUIVALENTS, END OF PERIOD	$	115		$	—		$	22,494		$	—		$	22,609

25

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis should be read in conjunction with accompanying condensed consolidated financial statements and related notes included in this Form 10-Q. It contains forward looking statements that reflect our future plans, estimates, beliefs and expected performance. The forward looking statements are dependent upon events, risks and uncertainties that may be outside our control. Our actual results could differ materially from those discussed in these forward looking statements. Factors that could cause or contribute to such differences include, but are not limited to, market prices for natural gas and oil, economic and competitive conditions, regulatory changes, changes due to the adoption of SFAS No. 157, estimates of proved reserves, potential failure to achieve production from development projects, capital expenditures and other uncertainties, as well as those factors discussed below and elsewhere in this Form 10-Q and in our Annual Report on Form 10-K for the year ended December 31, 2007, particularly in “Risk Factors” and “Cautionary Notes Regarding Forward Looking Statements”, all of which are difficult to predict. In light of these risks, uncertainties and assumptions, the forward looking events discussed may not occur.

Overview

We are an independent energy company engaged in the exploration, development and production of natural gas and oil in the United States and Australia. Our principal business activities include the identification, acquisition, and subsequent exploration and development of natural gas and oil properties. Our emphasis is on prospective deep structures identified through seismic and other analytical techniques as well as unconventional natural gas reserves, such as coalbed methane (“CBM”). We are also pursuing unconventional natural gas exploration in the deep Bossier play in the Hilltop area in East Texas. Our primary CBM properties are in the United States in the Powder River Basin in Wyoming and Montana and in the Gunnedah and Gippsland Basins of Australia.

Hilltop Area, East Texas

Hilltop Area, East Texas. The majority of our activities have been in the deep Bossier and Knowles Limestone plays in the Hilltop area, located in East Texas approximately midway between Dallas and Houston in Leon and Robertson Counties. This exploration play has attracted some of the largest and most active operators in the U.S. Wells in this area target multiple potentially productive natural gas formations and are typically characterized by high initial production, significant decline rates and long-lived reserves.

Our first successful operated well was spudded in 2003 and placed on production in September 2004. As of March 31, 2008, we had successfully completed 14 out of 15 deep Bossier wells and four out of four Knowles Limestone wells. As of March 31, 2008, we were drilling 2 gross (1.4 net) Bossier wells and 1 gross (0.5 net) Knowles Limestone wells.

In early 2008, we drilled the Holmes #1 well to a total depth of 18,700 feet and, based on drilling, core and log analysis, encountered one Bossier sand that will be completed for production. The well is scheduled to be completed and placed on production in mid-May 2008. The Holmes #1 is an immediate offset to the successful F-K #1 well.

We are drilling the Lone Oak Ranch #6 well (LOR #6) to target middle Bossier sands. The LOR #6 is currently drilling at 13,774 feet and is expected to reach total depth in early June. The LOR #6 is being drilled using slim-hole casing design at an estimated cost of $8.0 million to drill and complete the well. We are also side-tracking the LOR #4 well horizontal section in order to re-complete the well using a strata-pack system that will allow for multiple acid fracture stimulations of the Knowles Limestone pay zones. The LOR #4 was originally completed as an open-hole well with no acid fracture stimulation.

We drilled the Brunette #1, a horizontal Knowles Limestone well, to a total measured depth of 15,251 feet (total vertical depth of 13,341 feet). The well encountered approximately 640 feet of reservoir quality formation within the 1,367-foot horizontal section of the wellbore. The Brunette #1 was stimulated

26

and placed on production in mid-April 2008 and is flowing at a gross stabilized rate of 1.0 MMcf per day. Several mechanical issues were encountered in the completion of the Brunette #1 well that appear to be restricting the sales rate. We will monitor well performance for approximately 60 days before implementing any remedial operations to enhance production.

For the three months ended March 31, 2008, net production from the Hilltop area averaged 20.9 MMcf per day, up approximately 40% from 15.0 MMcf per day for the fourth quarter on 2007 and up approximately 121% from 9.5 MMcf per day for the three months ended March 31, 2007.

For the balance of 2008, we anticipate a two-rig drilling program in East Texas with one rig dedicated to drilling deep Bossier wells and the second rig dedicated to drilling horizontal Knowles Limestone wells.

Coalbed Methane – Powder River Basin, Wyoming and Montana

We own an approximate 40% average working interest in approximately 55,000 gross (21,900 net) acres in the Powder River Basin of Wyoming and Montana. The Powder River Basin has been an important natural gas producing area for nearly 100 years. Generally, CBM wells are shallow and less costly than conventional natural gas wells. Our primary areas of activity in the Powder River Basin are the Squaw Creek, Ring of Fire and adjacent fields, all of which are located north of Gillette, Wyoming in an active drilling area.

During the three months ended March 31, 2008, we were participating in the drilling of 3 gross (1.5 net) CBM wells. For the three months ended March 31, 2008, our average net production from our CBM properties in the Powder River Basin was approximately 5.6 MMcf per day, up from 4.5 MMcf per day for the three months ended March 31, 2007. We anticipate continuing our recompletion and drilling program in 2008. Our activity level will be influenced by regional natural gas prices. Regional prices in early 2008 have rebounded to, or above, historic price levels.

Coalbed Methane – PEL 238, Gunnedah Basin, New South Wales, Australia

We have a 35% interest in PEL 238, a CBM exploratory property covering approximately 2.2 million gross (786,000 net) acres, located in the Gunnedah Basin of New South Wales, approximately 250 miles northwest of Sydney, Australia, near the town of Narrabri. We believe that the strategic location of the properties and potential CBM reserves near the large natural gas markets in the Sydney-Newcastle-Wollongong area and the concession’s location relative to other developing gas markets should create a competitive marketing advantage for the natural gas reserves that may be developed on PEL 238.

Extensive coring of the coal on PEL 238 by the Australian government has provided a basic understanding of the coal resources and potential CBM resource in place on our license. Two primary coal seams are found on the PEL 238 license, the Late Permian aged Hoskisson coal formation and the Early Permian aged Maules Creek coal formation.

During 2007, we and our Australian joint venture partner, Eastern Star Gas Limited (ESG), were approached by potential buyers with an interest in potentially contracting for up to 1 Tcf of natural gas from PEL 238 to be delivered over a 15 to 20 year period commencing in late 2010, though there is no assurance that such an agreement will ultimately be reached or that such volumes will ultimately be produced from PEL 238. In March 2007, we announced that we and our joint venture partner had executed a Memorandum of Understanding (“MOU”) with Macquarie Generation, a New South Wales government-owned electricity generator, for the potential future supply of natural gas for its Bayswater power station. In November 2007, we announced that we and our joint venture partner had entered into a second MOU with Babcock & Brown to supply gas from the PEL 238 and PEL 433 concessions for use in the generation of electricity.

In September 2007, our independent petroleum engineers, Netherland Sewell & Associates, Inc., certified a quantity of proved and probable reserves under guidelines established by the Society of

27

Petroleum Engineers, as a result of the success of one of our pilot production projects on PEL 238. These reserves, however, are not yet established as proved reserves under Securities and Exchange Commission, or SEC, guidelines nor can we assure that other unevaluated acreage will contain similar reserves.

Beginning in 2008, we and our joint venture partner have expanded our pilot production drilling program on the PEL 238 concession and recently successfully completed the drilling of the first test corehole, the Dewhurst #2, in a 20-well exploration and appraisal corehole drilling program on PEL 238. The results of the Dewhurst #2 confirmed the presence of a thick Bohena coal seam developed to the south and east of the Bibblewindi pilot production area. The Dewhurst #2 encountered approximately 39 meters of coal within the Black Jack and Maules Creek coal formations, including approximately 18.2 meters in the targeted Bohena seam of which 14.7 meters was found in a single coal zone. We have commenced drilling the second test corehole of the 2008 gas reserves upgrade program, the Dewhurst #3, which is located approximately 2.2 miles east of the Dewhurst #2.

Coal Bed Methane – PEL 433-434, Gunnedah Basin, New South Wales, Australia

PEL 433 is located south of PEL 238, where we and our joint venture partner, ESG, are developing the Gunnedah Basin Gas Project (Coal Seam Gas Joint Venture). Coal evaluation core-hole drilling completed during the 1970s and 1980s by the New South Wales government identified the distribution and thickness of the coal measures within a portion of PEL 433. The Hoskissons Coal Seam is believed to be approximately 4 to 6 meters thick and widely distributed within the eastern part of PEL 433. There has been no previous coal seam gas exploration and evaluation work in the area, and there is no information on gas content, gas composition or coal permeability.

In July 2007, we entered into a Farm-In Agreement with ESG under which we have earned a 35% working interest in the PEL 433 and adjoining PEL 434 properties. Under the terms of the Farm-In Agreement, we paid the costs of a two core-hole program and the related costs of the evaluation of the coal reservoirs intersected by the core-holes. The two corehole drilling program commenced during July 2007 and evaluated the coal seam gas potential of the Hoskissons Coal Seam within the Late Permian Black Jack Coal Measures. Additional coring may be undertaken on PEL 433 to provide further data on coal depth, thickness, permeability, gas contents and composition.

Coalbed Methane – EL 4416, Gippsland Basin, Victoria, Australia

We have a 75% interest in the CBM rights in EL 4416, an approximate 1.0 million gross (750,000 net) acre property covering a substantial part of the onshore portion of the Gippsland Basin of Victoria, Australia, located approximately 130 miles east of Melbourne. The EL 4416 property is well situated with three existing natural gas transmission lines running through the license area from productive offshore fields to a large natural gas processing facility and then to markets near Sydney, Melbourne and in Tasmania. The EL 4416 coal is classified as low-rank brown coal. The Victorian government has extensively evaluated the potential coal resources through detailed coal resource studies. Due to our large acreage position and the fact that this thick coal is present over a large percentage of the license area, the CBM resource potential is believed to be significant.

During 2006, we began initial long-term testing of the first of two wells completed on EL 4416. Before a pump failure, early water production had been significant, indicating permeability in the targeted coal seam. In late 2006, we pre-funded $6.5 million for a 10-well drilling program, which commenced drilling operations in late 2006. The program included the establishment of two “five-spot” pilots, one incorporating two existing wells and two wells designed to test for the presence and production potential of the coal at additional locations within the license area. In one of the two previously drilled wells, we have installed larger capacity pumps to facilitate de-watering operations.

Prior to the completion of the 10-well program mentioned above, Gastar and the operator of EL 4416, a subsidiary of GeoStar Corporation (“GeoStar”), became involved in a number of disputes concerning Gastar’s right to an assignment of its interest in EL 4416 and other jointly-owned properties. As a result, the operator has not provided Gastar with information concerning the results of the 10-well

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drilling program nor an accounting for the use of the funds provided for the drilling of the 10 CBM wells. While we believe we have good beneficial title to our interest in EL 4416, the subsidiary of GeoStar has not delivered to us a title assignment of our interest in a form to be recorded with Australian government officials. We have sent a letter to GeoStar demanding the arbitration of these issues. An arbitration hearing is currently scheduled for June 2008, but the hearing date is subject to change. See Note 12, “Commitments and Contingencies – Litigation”.

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 Form 10-Q.

The following table gives information about production volumes and prices of natural gas and oil for the periods indicated:

	For the Three Months Ended March 31,
	2008		2007
Production:
Natural gas (MMcf)		2,406		1,253
Oil (MBbl)		1		3
Total (MMcfe)		2,413		1,272
Total (MMcfed)		26.5		14.1
Average sales prices:
Natural gas (per Mcf), including impact of realized hedging activities	$	6.96	$	5.86
Oil (per Bbl)	$	96.84	$	55.05

Three Months Ended March 31, 2008 compared to the Three Months Ended March 31, 2007

Revenues.Substantially all of our revenues are derived from the production of natural gas in the United States. Natural gas and oil revenues were $16.8 million for the three months ended March 31, 2008, up 124% from $7.5 million for the three months ended March 31, 2007. Of the increase in revenues, 72% was due to an 88% increase in natural gas production volumes, primarily in East Texas, and 28% of the increase was due to a 19% increase in prices. During the three months ended March 31, 2008, approximately 44% of our natural gas production was hedged. The realized effect of hedging on natural gas sales was a decrease of $232,000 in revenues resulting in a decrease in total price received from $7.05 per Mcf to $6.96 per Mcf.

Unrealized natural gas hedge loss of $1.4 million is comprised of $169,000 of ineffectiveness and $1.2 million related to the time value of the costless collars. For the remainder of 2008, we have approximately 50% of our estimated gas production hedged.

Production taxes. We reported production taxes of $269,000 for the three months ended March 31, 2008, compared to $294,000 for the three months ended March 31, 2007. The lower overall production tax level is the result of refunds and abatements of severance taxes due to “tight sands” production on certain of our Hilltop wells.

Lease operating expenses. We reported lease operating expenses of $1.5 million for the three months ended March 31, 2008, down from $1.7 million for the three months ended March 31, 2007. Our lease operating expenses were $0.64 per Mcfe for the three months ended March 31, 2008, compared to $1.33 per Mcfe for the comparable period in 2007. This decrease was due to lower ad valorem taxes, workover expense and the elimination of lease costs associated with natural gas treatment plants in East Texas. This decrease was partially offset by an increased number of producing wells and increased production.

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Transportation and treating. We reported transportation expenses of $459,000 for the three months ended March 31, 2008, up from 323,000 for the three months ended March 31, 2007. This increase was primarily due to increased production and prices in Wyoming.

Depreciation, depletion and amortization.We reported depreciation, depletion and amortization (“DD&A”) of $6.4 million for the three months ended March 31, 2008, up from $4.3 million for the three months ended March 31, 2007. The increase in DD&A expense was the result of a 90% increase in production, primarily attributable to new East Texas wells drilled during 2007. The DD&A rate for the three months ended March 31, 2008 was $2.66 per Mcfe, as compared to $3.41 for the comparable period in 2007.

General and administrative.We reported general and administrative expenses of $4.3 million for the three months ended March 31, 2008, down from $6.8 million for the three months ended March 31, 2007. This decrease in general and administrative expenses was primarily due to an allowance for doubtful accounts of $3.6 million recorded in the three months ended March 31, 2007, which was partially offset by an increase in professional service charges, including legal costs and personnel costs. Non-cash stock-based compensation expense pursuant to the SFAS 123R, which is included in general and administrative expenses, was $856,000 and $1.2 million for the three months ended March 31, 2008 and 2007, respectively.

Litigation settlement expense. The $1.4 million litigation settlement expense incurred in the three months ended March 31, 2007 was primarily the result of an accrual related to a proposed settlement with GeoStar on certain matters, which was never settled. There was no litigation settlement expense for the three months ended March 31, 2008.

Interest expense.We reported interest expense of $2.1 million for the three months ended March 31, 2008, compared to $3.9 million for the three months ended March 31, 2007. The decrease in interest expense was primarily the result of $2.4 million of interest being capitalized during the three months ended March 31, 2008, resulting from capital activity expansion in Texas and Australia, which was partially offset by higher interest expense on the new 12 ³/4% senior secured notes. There was no capitalized interest recorded in the 2007 period.

Liquidity and Capital Resources

At March 31, 2008, we had cash and cash equivalents of $79.0 million and $16.9 million of borrowing availability under our bank revolving credit facility. For the three months ended March 31, 2008, we reported cash flow from operations of $14.3 million, up from $281,000 of cash flow from operations for the three months ended March 31, 2007. This increase resulted primarily from a 88% increase in production volumes and a 19% increase in prices. Capital expenditures on natural gas and oil properties totaled $20.0 million for the three months ended March 31, 2008.

Covenants in our 12 ³/4% Senior Secured Notes Indenture, our indenture governing our 9.75% convertible senior unsecured subordinated debentures and our Revolving Credit Facility agreement require us to make an offer to repurchase or repay all of the outstanding indebtedness thereunder in the event of a change of control of the Company, as defined in the respective agreements. Each of the indentures provides that if there is a change of control of the Company, as defined in the respective indenture, we are required to make an offer to each holder to repurchase all or any part of the 12 ³/4% Senior Secured Notes or the 9.75% convertible senior unsecured subordinated debentures, as the case may be, at 101% of the aggregate principal amount of the notes or debentures tendered for repurchase, plus accrued and unpaid interest. In the event of a change of control, as defined under the Revolving Credit Facility Agreement, all obligations under the Revolving Credit Facility will become immediately due and payable. If the change of control event occurs in one or more of these agreements, we may not have adequate financing available to meet the resulting payment obligations.

We continually evaluate our capital needs and compare them to our capital resources. To execute our operational plans, particularly our drilling plans in East Texas and Australia, additional funds

30

will be needed for acreage acquisition, seismic and other geologic analysis, drilling, undertaking completion activities and for general corporate purposes. We may have to significantly reduce our drilling and development program if our internally generated cash flow from operations and cash flow from financing activities are not sufficient to pay debt service, corporate overhead and expenditures associated with our projected drilling and development activities. We expect to fund these expenditures from internally generated cash flow, cash on hand, sales of assets and the issuance of additional debt or equity. We may also attempt to balance future capital expenditures through joint venture development of certain properties with industry partners. We cannot be certain that future funds will be available to fully execute our current business plan.

Our 2008 capital expenditures under our business plan are estimated to total approximately $65.4 million, of which $43.4 million is estimated to be spent on unconventional natural gas and oil exploration and development operations in East Texas, $7.4 million is estimated to be spent on CBM projects and additional projects in the United States and $14.6 million is estimated to be spent on CBM projects in Australia. Based on our current budget, we have sufficient capital, together with internally generated cash flow, to fund our exploration and development activities in East Texas and Australia for 2008 and a significant portion of our 2009 projected capital needs.

Our cash flow and ability to raise capital are highly dependent upon natural gas pricing. A material decrease in current and projected natural gas prices could impact our ability to fund future activities, impair our ability to raise additional capital on acceptable terms and result in a financial covenant default under the 12 ³/4% Senior Secured Notes, resulting in mandatory principal reduction under certain conditions. It may be difficult for us to raise capital through the issuance of common shares due to the pending GeoStar litigation.

In the fourth quarter of 2007 and the first quarter of 2008, we entered into various costless collar transactions with counterparties. The volumes currently hedged represents approximately 50% of 2008 and 15% of 2009 projected production.

Covenants in our 12 ³/4% Senior Secured Notes Indenture and our Revolving Credit Facility Agreement restrict us from hedging more than 75% of the projected production from proved developed producing reserves.

At March 31, 2008, we were in compliance with all debt covenants.

Off Balance Sheet Arrangements

As of March 31, 2008, we had no off balance sheet arrangements. We have no plans to enter into any off balance sheet arrangements in the foreseeable future.

Critical Accounting Policies and Estimates

The preparation of financial statements in conformity with accounting 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 Note 2 of the notes to our condensed consolidated financial statements in our Annual Report on Form 10-K for the year ended December 31, 2007.

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For information as to new accounting pronouncements, see Note 1 to our condensed consolidated financial statements in this Form 10-Q.

Item 3. Quantitative and Qualitative Disclosure of Market Risk

Commodity Price Risk

Our major commodity price risk exposure is to the prices received for our natural gas production. 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. We have entered into hedge transactions to mitigate our commodity pricing risk. For the three months ended March 31, 2008, a 10% change in the prices received for natural gas production would have had an approximate $1.7 million impact on our revenues before mitigating factors that might result from having hedge transactions in place. See Note 5 to our condensed consolidated financial statements for additional information on our hedging activities.

Interest Rate Risk

The carrying value of our debt approximates fair value. At March 31, 2008, we had approximately $133.3 million in principal amount of long-term debt, all of which was at a fixed interest rate. A 10% fluctuation in interest rates would have no impact on annual interest expense.

Currency Translation Risk

Our revenues and expenses and the majority of our capital expenditures are primarily in U.S. dollars, thus limiting our exposure to currency translation risk. During the three months ended March 31, 2008, we spent approximately $860,000 of capital expenditures on our Australian activities. We have no plans in the foreseeable future to implement hedges or financial instruments to manage international currency changes.

Item 4. Controls and Procedures

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

As required by SEC Rule 13a-15(b), we have evaluated, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this report. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by the Company in reports that it files under the Exchange Act is accumulated and communicated to the Company’s management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Our principal executive officer and principal financial officer have concluded that our current disclosure controls and procedures were effective as of March 31, 2008 at the reasonable assurance level.

Changes in Internal Control over Financial Reporting

There was no change in our internal control over financial reporting during the quarter ended March 31, 2008 that materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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PART II – OTHER INFORMATION

Item 1. Legal Proceedings

A discussion of current legal proceedings is set forth in Note 12 of the notes to our condensed consolidated financial statements in this Form 10-Q.

Item 1A. Risk Factors

In addition to other information set forth in this report, you should carefully consider the factors discussed under the heading “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2007, which could materially affect our business, financial condition and future results. The risk factors described in our Annual Report on Form 10-K are not the only risk factors facing our Company. Additional risk factors 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. Default Upon Senior Securities

None.

Item 4. Submission of Matters to a Vote of Security Holders

None

Item 5. Other Information

None.

Item 6. Exhibits

The following is a list of exhibits filed as part of this Form 10-Q. Where so indicated by a note, exhibits, which were previously filed, are incorporated herein by reference.

Exhibit Number	Description
31.1	Certification of chief executive officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.†
31.2	Certification of chief financial officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.†
32.1	Certification of the chief executive officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.††
32.2	Certification of the chief financial officer pursuant Section 906 of the Sarbanes-Oxley Act of 2002.††

† Filed herewith.

†† Furnished herewith.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	GASTAR EXPLORATION LTD.
Date: May 12, 2008	By:	/s/ J. RUSSELL PORTER
		J. Russell Porter
		Chairman, President and Chief Executive Officer
		(principal executive officer)
Date: May 12, 2008	By:	/s/ MICHAEL A. GERLICH
		Michael A. Gerlich
		Vice President and Chief Financial Officer
		(principal financial and accounting officer)

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EXHIBIT INDEX

Exhibit Number	Description
3.1	Amended and Restated Articles of Incorporation of Gastar Exploration Ltd. (incorporated herein by reference to Appendix B to the Company’s Proxy Statement for the Annual and Special Meeting of Shareholders dated April 30, 2007 to be held June 1, 2007.
3(ii)	Bylaws of Gastar Exploration Ltd. approved at March 31, 2000 and amended August 21, 2006 (incorporated herein by reference to Exhibit 3(ii) of the Company’s Current Report on Form 8-K dated December 19, 2006. File No. 001-37214).
4.1	Indenture dated November 12, 2004 between Gastar Exploration Ltd. and CIBC Mellon Trust Company as trustee (incorporated by reference to Exhibit 4.1 of the Company’s Registration Statement on Form S-1, filed on August 12, 2005. Registration No. 333-127498).
4.2	Form of 9.75% Convertible Senior Unsecured Subordinated Debenture of Gastar Exploration Ltd. (incorporated by reference to Exhibit 4.2 of the Company’s Registration Statement on Form S-1, filed on August 12, 2005. Registration No. 333-127498).
4.3	Agency Agreement dated as of November 12, 2004 between Gastar Exploration Ltd. and Westwind Partners Inc. in connection with issuances of 9.75% Convertible Senior Unsecured Subordinated Debenture of Gastar Exploration Ltd. (incorporated by reference to Exhibit 4.4 of the Company’s Registration Statement on Form S-1, filed on August 12, 2005. Registration No. 333-127498).
4.4	Form of Subscription Agreement for U.S. purchasers of 9.75% Convertible Senior Unsecured Subordinated Debenture of Gastar Exploration Ltd (incorporated by reference to Exhibit 4.5 of the Company’s Registration Statement on Form S-1, filed on August 12, 2005. Registration No. 333-127498).
4.5	Form of Subscription Agreement for foreign purchasers of 9.75% Convertible Senior Unsecured Subordinated Debenture of Gastar Exploration Ltd. (incorporated by reference to Exhibit 4.6 of the Company’s Registration Statement on Form S-1, filed on August 12, 2005. Registration No. 333-127498).
4.6	Registration Rights Agreement dated as of June 17, 2005, by and among Gastar Exploration Ltd. and the purchasers named therein (incorporated by reference to Exhibit 4.9 of the Company’s Registration Statement on Form S-1, filed on August 12, 2005. Registration No. 333-127498).
4.7	Form of Subscription Agreement for U.S. purchasers of common shares of Gastar Exploration Ltd. in a private placement dated June 30, 2005 (incorporated by reference to Exhibit 4.10 of the Company’s Registration Statement on Form S-1, filed on August 12, 2005. Registration No. 333-127498).
4.8	Form of Subscription Agreement for foreign purchasers of common shares of Gastar Exploration Ltd. in a private placement dated June 30, 2005 (incorporated by reference to Exhibit 4.11 of the Company’s Registration Statement on Form S-1, filed on August 12, 2005. Registration No. 333-127498).
4.9	Form of 10% subordinated note issued June 2004 (incorporated by reference to Exhibit 4.14 of the Company’s Amendment No. 4 to Registration Statement on Form S-1/A, filed on December 22, 2005. Registration No. 333-127498).
4.10	Form of warrant to purchase common shares of Gastar Exploration Ltd issued in connection with the sale of 10% subordinated notes in June 2004 (incorporated by reference to Exhibit 4.15 of the Company’s Registration Statement on Form S-1, filed on August 12, 2005. Registration No. 333-127498).
4.11	Agreement between Gastar Exploration Ltd. and GeoStar Corporation dated August 11, 2005 (incorporated by reference to Exhibit 4.17 of the Company’s Amendment No. 1 to Registration Statement on Form S-1/A, filed on October 30, 2005. Registration No. 333-127498).
4.12	Common Share Purchase Agreement between Gastar Exploration Ltd. and Chesapeake Energy Corporation dated November 4, 2005 (incorporated by reference to Exhibit 4.19 of the Company’s Amendment No. 2 to Registration Statement on Form S-1/A, filed on November 22, 2005. Registration No. 333-127498).
4.13	Registration Rights Agreement between Gastar Exploration Ltd. and Chesapeake Energy Corporation dated November 4, 2005 (incorporated by reference to Exhibit 4.20 of the Company’s Amendment No. 2 to Registration Statement on Form S-1/A, filed on November 22, 2005. Registration No. 333-127498).
4.14	Facsimile of common share certificate of Gastar Exploration Ltd. (incorporated by reference to Exhibit 4.21 of the Company’s Amendment No. 3 to Registration Statement on Form S-1/A, dated December 15, 2005. Registration No. 333-127498).
4.15	Form of Subscription Agreement for private offering of 25.0 million common shares (incorporated by reference to the Company’s Current Report on Form 8-K dated November 15, 2006.)

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4.16	Indenture related to the 12 3/4% Senior Secured Notes due November 29, 2012, dated as of November 29, 2007, between Gastar Exploration USA, Inc., Gastar Exploration Ltd., Wells Fargo Bank, National Association, as Trustee and Collateral Agent and each of the other Guarantors party thereto (including the form of 12 3/4% Senior Secured Note due 2012) 2007 (incorporated by reference to the Company’s Current Report on Form 8-K dated December 4, 2007).
4.17	Registration Rights Agreement, dated as of November 29, 2007, among Gastar Exploration USA, Inc., Gastar Exploration Ltd., each of the other Guarantors party thereto, Jefferies & Company, Inc., Johnson Rice & Company L.L.C. and Pritchard Capital Partners, LLC2007 (incorporated by reference to the Company’s Current Report on Form 8-K dated December 4, 2007).
4.18	Intercreditor Agreement dated November 29, 2007 among Gastar Exploration USA, Inc., Gastar Exploration Ltd., each of the Guarantors party thereto, Amegy Bank National Association, as First Priority Agent, and Wells Fargo National Association, as Second Priority Agent2007 (incorporated by reference to the Company’s Current Report on Form 8-K dated November 13, 2007).
4.19	Credit Agreement, dated November 29, 2007, among Gastar Exploration USA, Inc., the Guarantors party thereto and Amegy Bank National Association as Administrative Agent and Letter of Credit Issuer2007 (incorporated by reference to the Company’s Current Report on Form 8-K dated December 4, 2007).
10.1*	The Gastar Exploration Ltd. 2002 Stock Option Plan, dated July 5, 2002 as periodically amended (incorporated by reference to Exhibit 4.1 of the Company’s Current Report on Form 8-K dated December 4, 2006. File No. 001-32714).
10.2*	Employment Agreement dated March 23, 2005 by and among First Sourcenergy Wyoming, Inc., Gastar Exploration Ltd. and J. Russell Porter (incorporated by reference to Exhibit 10.2 of the Company’s Registration Statement on Form S-1, filed on August 12, 2005. Registration No. 333-127498).
10.3*	Employment Agreement dated April 26, 2005 by and among First Sourcenergy Wyoming, Inc., Gastar Exploration Ltd. and Michael A Gerlich (incorporated by reference to Exhibit 10.3 of the Company’s Registration Statement on Form S-1, filed on August 12, 2005. Registration No. 333-127498).
10.4	Purchase and Sale Agreement between GeoStar Corporation and Gastar Exploration Ltd. covering Wyoming and Montana producing properties dated June 16, 2005 (incorporated by reference to Exhibit 10.4 of the Company’s Amendment No. 1 to Registration Statement on Form S-1/A, filed on October 30, 2005. Registration No. 333-127498).
10.5	Purchase and Sale Agreement between GeoStar Corporation and Gastar Exploration Ltd. covering Wyoming and Montana non-producing properties dated June 16, 2005 (incorporated by reference to Exhibit 10.5 of the Company’s Amendment No. 1 to Registration Statement on Form S-1/A, filed on October 30, 2005. Registration No. 333-127498).
10.6	Purchase and Sale Agreement between GeoStar Corporation and Gastar Exploration Ltd. covering Texas producing properties dated June 16, 2005 (incorporated by reference to Exhibit 10.6 of the Company’s Amendment No. 1 to Registration Statement on Form S-1/A, filed on October 30, 2005. Registration No. 333-127498).
10.7	Purchase and Sale Agreement between GeoStar Corporation and Gastar Exploration Ltd. covering Texas non-producing properties dated June 16, 2005 (incorporated by reference to Exhibit 10.7 of the Company’s Amendment No. 1 to Registration Statement on Form S-1/A, filed on October 30, 2005. Registration No. 333-127498).
10.8	Participation and Operating Agreement between GeoStar Corporation and Gastar Exploration Ltd. dated June 15, 2001 (incorporated by reference to Exhibit 4.19 of the Company’s Amendment No. 2 to Registration Statement on Form S-1/A, filed on November 22, 2005. Registration No. 333-127498).
10.9	Promissory Note for $15 million between GeoStar Corporation and Gastar Exploration Ltd. dated August 11, 2001 (incorporated by reference to Exhibit 10.9 of the Company’s Amendment No. 1 to Registration Statement on Form S-1/A, filed on October 30, 2005. Registration No. 333-127498).
10.10*	Form of Gastar officer stock option grant (incorporated herein by reference to Exhibit 10.10 of the Company’s annual Report on form 10-K for the fiscal year ended December 31, 2005. File No. 001-32714).
10.11*	Gastar Exploration Ltd. 2006 Long-Term Stock Incentive Plan (incorporated herein by reference to Exhibit 10.11 of the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2006. File No. 001-32714).

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10.12*	Form of Indemnity Agreement for Directors and Certain Executive Officers (incorporated herein by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K dated December 19, 2006. File No. 001-32714).
10.13*	Form of Gastar Exploration Ltd. Employee Change of Control Severance Plan effective as of March 23, 2007 (incorporated by reference to Exhibit 10.13 of the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2006. File No. 001-32714).
10.14	Common Share Purchase Agreement between Gastar Exploration Ltd. and Navasota Resources, L.P. dated as of May 9, 2007, in connection with the issuance and sale of 10,000,000 common shares (incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K dated May 15, 2007. File No. 001-32714).
10.15	Registration Rights Agreement by and between Gastar Exploration Ltd. and Navasota Resources, L.P. dated as of May 9, 2007 (incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K dated May 15, 2007. File No. 001-32714).
10.16	Ratification and Assumption of LOI between and among Gastar Exploration Ltd., Gastar Exploration Texas LP and Navasota Resources, L.P. dated May 9, 2007, with Letter of Intent dated April 27, 2007 between and among Gastar Exploration Ltd., Gastar Exploration Texas LP, Chesapeake Energy Corporation and Chesapeake Exploration Limited Partnership, attached thereto as Exhibit A (incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K dated May 15, 2007. File No. 001-32714).
10.17*	Letter Agreement dated July 5, 2007, which sets forth the terms of the appointment of Jeffrey C. Pettit as Vice President and Chief Operating Officer of Gastar Exploration Ltd. (incorporated herein by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K dated August 21, 2007. File No. 001-32714).
10.18*	Form of Gastar Exploration Ltd. Employee Change of Control Severance Plan effective as of March 23, 2007 and as amended and restated effective February 15, 2008 (incorporated herein by reference to Exhibit 21.1 of the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2007. File No. 001-32714).
14.1	Gastar Exploration Ltd. Code of Ethics, adopted effective December 15, 2005 (incorporated herein by reference to Exhibit 14.1 of the Company’s Amendment No 4 to Registration Statement on Form S-1/A, dated December 22, 2005, Registration No. 333-27498).
21.1	Subsidiaries of Gastar Exploration Ltd. (incorporated herein by reference to Exhibit 21.1 of the Company’s annual Report on Form 10-K for the fiscal year ended December 31, 2007. File No. 001-32714).
31.1†	Certification of chief executive officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2†	Certification of chief financial officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1††	Certification of chief executive officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2††	Certification of chief financial officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

* Management contract or compensatory plan or arrangement.

† Filed herewith.

†† Furnished herewith.

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