AMERICAN NOBLE GAS, INC. - Quarter Report: 2008 June (Form 10-Q)

 

 

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

 

FORM 10-Q

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

For the quarterly period ended June 30, 2008

OR

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

INFINITY ENERGY RESOURCES, INC.

(Exact Name of Registrant as Specified in its Charter)

Delaware		20-3126427
(State of Incorporation)		(I.R.S. Employer Identification Number)

633 Seventeenth Street, Suite 1800, Denver, Colorado 80202
(Address of Principal Executive Offices, Including Zip Code)

(720) 932-7800
(Registrant’s telephone number, including area code)

633 Seventeenth Street, Suite 1800
Denver, Colorado 80202
(Former name or former address, if changed since last report)

     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 þ No o

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

Large accelerated filer o		Accelerated filer þ
Non-accelerated filer  o		Smaller reporting company o
(Do not check if a 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 o No þ

     As of August 15, 2008, 17,869,375, shares of the Registrant’s $0.0001 par value Common Stock were outstanding.

 

 

TABLE OF CONTENTS

PART I Financial Information
Item 1. Financial Statements
Consolidated Balance Sheets			3
Consolidated Statements of Operations			4
Consolidated Statement of Changes in Stockholders’ Equity			5
Consolidated Statements of Cash Flows			6
Notes to Unaudited Consolidated Financial Statements			7
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations			16
Item 3. Quantitative and Qualitative Disclosures About Market Risk			22
Item 4. Controls and Procedures			22
PART II Other Information
Item 1. Legal Proceedings			23
Item 1A. Risk Factors			23
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			23
Item 3. Defaults Upon Senior Securities			23
Item 4. Submission of Matters to a Vote of Security Holders			23
Item 5. Other Information			23
Item 6. Exhibits			23
Signatures			24
Exhibits			25
Certification of Principal Executive Officer Pursuant to Section 302
Certification of Principal Financial Officer Pursuant to Section 302
Certifications Pursuant to Section 906

INFINITY ENERGY RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS
(UNAUDITED)
(in thousands, except share and per share amounts)

		June 30,				December 31,
		2008				2007
ASSETS
Current assets:
Cash and cash equivalents		$	1,238			$	741
Accounts receivable			741				1,164
Prepaid expenses and other			237				104
Prepaid severance taxes			—				675
Total current assets			2,216				2,684
Oil and gas properties, using full cost accounting, net of accumulated depreciation, depletion, amortization and ceiling write-down:
Proved			7,290				21,429
Unproved			11,556				17,097
Other assets, net			232				1,090
Total assets		$	21,294			$	42,300
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Current portion of debt		$	9,910			$	22,000
Accounts payable			1,405				5,472
Accrued liabilities			2,818				4,973
Current portion of asset retirement obligations			432				423
Total current liabilities			14,565				32,868
Long-term liabilities:
Production taxes payable and other liabilities			99				426
Asset retirement obligations, less current portion			518				1,087
Derivative liabilities			119				194
Total liabilities			15,301				34,575
Commitments and contingencies
Stockholders’ equity:
Preferred stock, par value $.0001 per share; 10,000,000 authorized shares, no shares issued and outstanding			—				—
Common stock, par value $.0001 per share; 75,000,000 authorized shares, 17,869,375 (2008) and 17,871,157 (2007) shares issued and outstanding			2				2
Additional paid-in-capital			79,716				79,371
Accumulated deficit			(73,725	)			(71,648	)
Total stockholders’ equity			5,993				7,725
Total liabilities and stockholders’ equity		$	21,294			$	42,300

See Notes to Unaudited Consolidated Financial Statements.

INFINITY ENERGY RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS
(UNAUDITED)
(in thousands, except per share data)

		For the Three Months								For the Six Months
		Ended June 30,								Ended June 30,
		2008				2007				2008				2007
Revenue
Oil and gas sales		$	1,286			$	2,533			$	2,486			$	4,632
Operating expenses
Oil and gas production expenses			622				1,262				1,402				3,320
Oil and gas production taxes			41				166				68				301
General and administrative expenses			812				753				1,609				1,717
Depreciation, depletion, amortization and accretion			385				1,871				777				3,004
Ceiling write-down of oil and gas properties			—				15,750				—				15,750
Total operating expenses			1,860				19,802				3,856				24,092
Operating loss			(574	)			(17,269	)			(1,370	)			(19,460	)
Other income (expense)
Interest expense, net of capitalization			(320	)			—				(776	)			—
Change in derivative fair value			1				1,223				(34	)			(351	)
Other			68				(13	)			103				(28	)
Total other income (expense)			(251	)			1,210				(707	)			(379	)
Net income (loss)		$	(825	)		$	(16,059	)		$	(2,077	)		$	(19,839	)
Basic and diluted net income (loss) per share:
Net income (loss)		$	(0.05	)		$	(0.90	)		$	(0.12	)		$	(1.11	)
Weighted average shares outstanding:
Basic and diluted			17,869				17,871				17,869				17,871

See Notes to Unaudited Consolidated Financial Statements.

INFINITY ENERGY RESOURCES, INC. AND SUBSIDIARIES

(in thousands, except share amounts)

																		Accumulated
										Additional								Other
		Common Stock								Paid-In				Accumulated				Comprehensive				Stockholders’
		Shares				Amount				Capital				Deficit				Loss				Equity
Balance, December 31, 2007			17,871,157			$	2				$ 79,371				$ (71,648	)			$           —				$   7,725
Forfeiture of common stock			(1,782	)			—				—				—				—				—
Stock-based compensation			—				—				345				—				—				345
Comprehensive loss:
Net loss			—				—				—				(2,077	)			(2,077	)			(2,077	)
Reclassifications			—				—				—				—
Total comprehensive loss																			$     (2,077	)
Balance, June 30, 2008			17,869,375			$	2				$ 79,716				$ (73,725	)			$           —				$   5,993

See Notes to Unaudited Consolidated Financial Statements.

INFINITY ENERGY RESOURCES, INC. AND SUBSIDIARIES

(in thousands)

		For the Six Months
		Ended June 30,
		2008				2007
Cash flows from operating activities:
Net loss		$	(2,077	)		$	(19,839	)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation, depletion, amortization and accretion			777				3,004
Ceiling write-down of oil and gas properties			—				15,750
Non-cash stock-based compensation expense			345				585
Change in fair value of derivative instruments			(75	)			(1,069	)
Unrealized loss on commodity derivative instruments			—				1,565
Gain on sales of assets			(17	)			—
Change in operating assets and liabilities:
Decrease in accounts receivable			423				87
(Increase) decrease in prepaid expenses and other			518				(107	)
Decrease in accounts payable and accrued liabilities			(2,569	)			(1,029	)
Net cash used in operating activities			(2,675	)			(1,053	)
Cash flows from investing activities:
Capital expenditures – exploration and production			(3,267	)			(15,808	)
Decrease in other assets			852				—
Proceeds from sale of fixed assets			17,677				—
Net cash provided by (used in) investing activities			15,262				(15,808	)
Cash flows from financing activities:
(Repayment of) proceeds from borrowings on debt			(12,090	)			17,000
Debt issuance costs			—				(865	)
Repayment of notes payable			—				(25	)
Net cash (used in) provided by financing activities			(12,090	)			16,110
Net increase (decrease) in cash and cash equivalents			497				(751	)
Cash and cash equivalents, beginning of period			741				872
Cash and cash equivalents, end of period		$	1,238			$	121

See Notes to Unaudited Consolidated Financial Statements.

INFINITY ENERGY RESOURCES, INC. AND SUBSIDIARIES

Note 1 — Nature of Operations, Basis of Presentation and Summary of Significant Accounting Policies

Nature of Operations

     Infinity Energy Resources, Inc. and its subsidiaries (collectively, “Infinity” or the “Company”) are engaged in the acquisition, exploration, development and production of natural gas and crude oil in the United States and the acquisition and exploration of oil and gas properties offshore Nicaragua in the Caribbean Sea.

Basis of Presentation

     The unaudited consolidated financial statements include the accounts of Infinity Energy Resources, Inc. and its wholly-owned subsidiaries, which include Infinity Oil and Gas of Texas, Inc., Infinity Oil & Gas of Wyoming, Inc., and Infinity Oil & Gas of Kansas, Inc. All significant intercompany balances and transactions have been eliminated in consolidation.

     The accompanying unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States for interim financial information. Accordingly, certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States have been condensed or omitted in this Quarterly Report on Form 10-Q pursuant to the rules and regulations of the United States Securities and Exchange Commission (“SEC”). In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included. The consolidated results of operations for the three and six months ended June 30, 2008, are not necessarily indicative of the results that may be expected for the year ending December 31, 2008. The accompanying unaudited consolidated financial statements should be read in conjunction with Infinity’s audited consolidated financial statements for the year ended December 31, 2007.

     On January 7, 2008, Infinity-Wyoming completed the sale of essentially all of its producing oil and gas properties in Colorado and Wyoming, along with 80% of the working interest owned by the Company in undeveloped leaseholds in Routt County, Colorado and Sweetwater County, Wyoming to Forest Oil Corporation, a New York corporation (“Forest”). The transaction resulted in the sale of approximately 62% of the Company’s proved reserve quantities and 73% of the standardized measure of discounted future net cash flow. In addition, concurrent with the sale, on December 27, 2007, Infinity-Texas entered into a Farmout and Acquisition Agreement (“Farmout Agreement”) for certain oil and gas leaseholds owned by Infinity-Texas in Erath County, Texas. The Farmout Agreement provides that Forest will operate and earn a 75% interest in the spacing unit for each well in a 10-well drilling program. If Forest completes the drilling program, Forest will earn a 50% interest in the approximate 25,000 remaining undeveloped net acres and existing Erath County infrastructure owned by Infinity-Texas. Infinity-Texas retains 100% of its interest in all previously completed wells and 100 acres surrounding each such completed well.

Liquidity; Going Concern

     As reflected in the accompanying unaudited Consolidated Statements of Operations, the Company has had a history of losses.  In addition, the Company has a significant working capital deficit and is currently experiencing substantial liquidity problems. As also discussed in Note 2, the Company is currently operating under the Second Forbearance Agreement, as amended, with Amegy Bank, N. A. (“Amegy”) under the Revolving Credit Facility.

     The Company entered into the Second Forbearance Agreement, under the Revolving Credit Facility as a result of the Company’s failure to meet substantially all financial and certain other covenants during certain periods of 2007. Under this agreement, Amegy agreed to forebear from exercising any remedies under the Revolving Credit Facility, the revolving note and the related loan documents and to temporarily waive the covered events of default through May 30, 2008. The Company was required to repay the borrowing base deficiency by May 30, 2008 through the sale of assets, refinancing of the loan or some other means of raising capital. The Company failed to comply with the terms of the Second Forbearance Agreement and is currently in discussions with Amegy regarding an extension of the forbearance period or a new forbearance agreement; however, we may be unable to reach agreement on these matters at all or on acceptable terms. Amegy is currently entitled to impose a default interest rate (prime plus 6.5%) or to declare an event of default, at which point the entire unpaid principal balance of the loan, together with all accrued and unpaid interest

and other amounts then owing to Amegy would become immediately due and payable. Amegy or other creditors may take action to enforce their rights with respect to outstanding obligations, and Infinity may be forced to liquidate. Because substantially all of the Company’s assets are collateral under the Revolving Credit Facility, if Amegy declares an event of default, it would be entitled to foreclose on and take possession of the Company’s assets.

     As a result, the Company has classified all $9,910,000 outstanding under the Revolving Credit Facility at June 30, 2008 as current liabilities in the accompanying Consolidated Balance Sheets. Concurrent with the sale of assets on January 7, 2008, the Company repaid $11,097,000 of principal outstanding under the Revolving Credit Facility, settled commodity derivative liabilities of $2,258,000, settled general and administrative liabilities of approximately $660,000 and established an escrow account in the amount of $3,700,000 ($438,000 of which remained at June 30, 2008) to settle exploration and operating liabilities of Infinity Oil and Gas of Texas, Inc. in the amount of $4,838,000. The Company continues to negotiate with and seek concessions from its trade creditors in order to satisfy its remaining 2007 obligations, which totaled approximately $700,000 at June 30, 2008.

     Due to the uncertainties related to these matters, there exists substantial doubt about the Company’s ability to continue as a going concern. The financial statements do not include any adjustments relating to the recoverability and classification of asset carrying amounts or the amount and classification of liabilities that might result should the Company be unable to continue as a going concern.

Management Estimates

     The preparation of unaudited consolidated financial statements in conformity with generally accepted accounting principles in the United States 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 unaudited consolidated 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 the unaudited consolidated financial statements include the estimated carrying value of unproved properties, the estimate of proved oil and gas reserve volumes and the related present value of estimated future net cash flows and the ceiling test applied to capitalized oil and gas properties, the estimated cost and timing related to asset retirement obligations, the estimated fair value of derivative liabilities and stock based awards and the realizability of deferred tax assets.

Oil and Gas Properties

     The Company follows the full cost method of accounting for exploration and development activities. Accordingly, all costs incurred in the acquisition, exploration, and development of properties (including costs of surrendered and abandoned leaseholds, delay lease rentals, dry holes and seismic costs) and the fair value of estimated future costs of site restoration, dismantlement, and abandonment activities are capitalized. Overhead related to exploration and development activities is also capitalized. The Company capitalized $8,000 and $242,000 of internal costs during the three months ended June 30, 2008 and 2007, respectively, and $38,000 and $444,000 during the six months ended June 30, 2008, and 2007, respectively. Costs associated with production and general corporate activities are expensed in the period incurred.

     Depletion of proved oil and gas properties is computed on the units-of-production method, with oil and gas being converted to a common unit of measure based on relative energy content, whereby capitalized costs, as adjusted for estimated future development costs and estimated asset retirement costs, are amortized over the total estimated proved reserve quantities. The costs of wells in progress and unevaluated properties, including directly related seismic costs and any related capitalized interest and capitalized internal costs, are not amortized. On a quarterly basis, such costs are evaluated for inclusion in the costs to be amortized resulting from the determination of proved reserves, impairments, or reductions in value. To the extent that the evaluation indicates these properties are impaired, the amount of the impairment is added to the capitalized costs to be amortized. Abandonments of unproved properties are accounted for as an adjustment to capitalized costs related to proved oil and gas properties, with no losses recognized.

     Proceeds from the sales of oil and gas properties are accounted for as adjustments to capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in income. Expenditures for maintenance and repairs are charged to oil and gas production expense in the period incurred.

     Pursuant to full cost accounting rules, the Company must perform a “ceiling test” each quarter. The ceiling test provides that capitalized costs less related accumulated depletion and deferred income taxes for each cost center may not exceed the sum of (1) the present value of future net revenue from estimated production of proved oil and gas reserves using current costs and prices, including the effects of derivative instruments accounted for as cash flow hedges but excluding the future cash outflows associated with settling

asset retirement obligations that have been accrued on the balance sheet, and a discount factor of 10%; plus (2) the cost of properties not being amortized, if any; plus (3) the lower of cost or estimated fair value of unproved properties included in the costs being amortized, if any; less (4) income tax effects related to differences in the book and tax basis of oil and gas properties. If capitalized costs exceed the ceiling, the excess must be charged to expense and may not be reversed in future periods.

     At June 30, 2008, the full cost ceiling exceeded the carrying value of the Company’s oil and gas properties, based upon a natural gas price of approximately $13.50 per Mcf in effect at that date. A decline in prices received for gas sales or an increase in operating costs or reductions in estimated economically recoverable quantities could result in the recognition of a ceiling write-down of oil and gas properties in a future period.

     Aggregate capitalized costs relating to the Company’s oil and gas producing activities, and related accumulated depreciation, depletion, amortization and ceiling write-downs are as follows:

		As of
		June 30,				December 31,
		2008				2007
		(in thousands)
Proved oil and gas properties		$	90,090				$  131,532
Unproved oil and gas properties			11,556				17,097
Total			101,646				148,629
Less accumulated depreciation, depletion, amortization and ceiling write-downs			(82,800	)			(110,103	)
Net capitalized costs		$	18,846				$    38,526

Derivative Instruments

     The Company accounts for derivative instruments or hedging activities under the provisions of Statement of Financial Accounting Standards (“SFAS”) No. 133, Accounting for Derivative Instruments and Hedging Activities. SFAS No. 133 requires the Company to record derivative instruments at their fair value. If the derivative is designated as a fair value hedge, the changes in the fair value of the derivative and of the hedged item attributable to the hedged risk are recognized in earnings. If the derivative is designated as a cash flow hedge, the effective portions of changes in the fair value of the derivative are recorded in other comprehensive income (loss) and are recognized in the statement of operations when the hedged item affects earnings. Ineffective portions of changes in the fair value of cash flow hedges, if any, are recognized in earnings. Changes in the fair value of derivatives that do not qualify for hedge treatment are recognized in earnings.

     The Company periodically hedges a portion of its oil and gas production through swap and collar agreements. The purpose of the hedges is to provide a measure of stability to the Company’s cash flows in an environment of volatile oil and gas prices and to manage the exposure to commodity price risk.

     As a result of certain terms, conditions and features included in certain warrants issued by the Company, those warrants are required to be accounted for as derivatives at estimated fair value.

Income Taxes

     The Company uses the asset and liability method of accounting for income taxes. This method requires the recognition of deferred tax liabilities and assets for the expected future tax consequences of temporary differences between financial accounting bases and tax bases of assets and liabilities. The tax benefits of tax loss carryforwards and other deferred taxes are recorded as an asset to the extent that management assesses the utilization of such assets to be more likely than not. When the future utilization of some portion of the deferred tax asset is determined not to be more likely than not, a valuation allowance is provided to reduce the recorded deferred tax asset. As of June 30, 2008 and December 31, 2007, the Company had recorded a full valuation allowance for its net deferred tax asset.

Comprehensive Income (Loss)

     The Company has elected to report comprehensive income (loss) in the consolidated statements of stockholders’ equity. Comprehensive income (loss) is composed of net income (loss) and all changes to stockholders’ equity, except those due to investments by stockholders, changes in additional paid-in-capital and distributions to stockholders. The only item included in comprehensive loss for the three and six months ended June 30, 2007 related to the effective portion of commodity derivative instruments.

Cash and cash equivalents

     For purposes of reporting cash flows, cash and cash equivalents consist of cash on hand and demand deposits with financial institutions. At times, the Company maintains deposits in financial institutions in excess of federally insured limits. Management monitors the soundness of the financial institutions and believes the Company’s risk is negligible. The Company considers all highly liquid investments with a maturity of three months or less when purchased to be cash equivalents. At June 30, 2008, cash and cash equivalents include $438,000 designated for the payment of outstanding trade payables associated with exploration activities in Erath County, Texas.

Prepaid Severance Taxes

     At June 30, 2008, and December 31, 2007, the Company had $161,000 and $737,000, respectively, of prepaid severance taxes related to estimated production tax refunds from the State of Texas, $675,000 of which was a current asset at December 31, 2007. The estimated refunds result from the September 2006 designation of the Barnett Shale in Erath County, Texas as a tight gas formation eligible for a reduced production tax rate. As a result of this designation, the Company reflects the payments of severance taxes for the eligible wells as a prepayment rather than as production tax expense.

Asset Retirement Obligations

     The Company records estimated future asset retirement obligations pursuant to the provisions of SFAS No. 143, Accounting for Asset Retirement Obligations. SFAS No. 143 requires entities to record the fair value of a liability for an asset retirement obligation in the period in which it is incurred with a corresponding increase in the carrying amount of the related long-lived asset. Subsequent to initial measurement, the asset retirement liability is required to be accreted each period to present value. The Company’s asset retirement obligations consist of costs related to the plugging of wells, the removal of facilities and equipment, and site restoration on oil and gas properties. Capitalized costs are depleted as a component of the full cost pool using the units of production method. The following table summarizes the activity for the Company’s asset retirement obligations for the six months ended June 30:

		2008				2007
		(in thousands)
Asset retirement obligations at beginning of period			$  1,510				$  1,602
Accretion expense			44				48
Liabilities incurred			—				33
Liabilities settled			—				(259	)
Liabilities settled through sale of assets			(604	)			—
Revisions of estimates			—				52
Asset retirement obligations at end of period			950				1,476
Less: current portion of asset retirement obligations			(432	)			(432	)
Asset retirement obligations, less current portion			$     518				$  1,044

Capitalized Interest

     The Company capitalizes interest costs to oil and gas properties on expenditures made in connection with exploration and development projects that are not subject to current depletion. Interest is capitalized only for the period that activities are in progress to bring these projects to their intended use. No interest was capitalized in the three months ended June 30, 2008. Interest costs capitalized in the three months ended June 30, 2007 were $277,000. Interest costs capitalized in the six months ended June 30, 2008, and 2007, were $154,000 and $442,000, respectively.

Intangible Assets

     During the three and six months ended June 30, 2007, the Company recorded amortization of deferred loan costs of $114,000 and $228,000, respectively using the effective interest method. The Company capitalizes amortization of loan costs to oil and gas properties on expenditures made in connection with exploration and development projects that are not subject to current depletion. Amortization of loan costs is capitalized only for the period that activities are in progress to bring these projects to their intended use. Total loan cost amortization capitalized in the three and six months ended June 30, 2007 was $114,000 and $228,000, respectively.

Fair Value of Financial Instruments

     The carrying values of the Company’s cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities represent the estimated fair value due to the short-term nature of the accounts.

     The carrying value of the Company’s debt under its Revolving Credit Facility represents its estimated fair value due to its short-term nature, its adjustable rate of interest and associated fees and expenses.

     The estimated fair value of the Company’s current derivative liabilities, all of which related to commodity swaps and collars at December 31, 2007, was estimated using year-end futures prices, volumes, delivery dates, and a present value factor commensurate with the derivative contract term as the Company’s swap and collar contracts were not actively traded.

     The estimated fair value of the Company’s non-current derivative liabilities, all of which relate to warrants, is estimated using various models and assumptions related to the term of the instruments, estimated volatility of the price of the Company’s common stock and interest rates, among other items (SFAS 157 fair value hierarchy level 2).

Earnings Per Share

     Basic income (loss) per common share is computed as net income (loss) divided by the weighted average number of common shares outstanding during the period. Diluted income (loss) per common share is computed as net income (loss) divided by the weighted average number of common shares and potential common shares, using the treasury stock method, outstanding during the period. For the three and six months ended June 30, 2008 and 2007, the Company’s common stock equivalents were anti-dilutive. Therefore, the impact of 7,686,000 and 8,393,000 common stock equivalents as of June 30, 2008 and 2007, respectively, were not included in the calculation of diluted loss per share because their effect was anti-dilutive.

Recent Accounting Pronouncements

     In September 2006, the FASB issued SFAS No. 157, Fair Value Measurements (“SFAS 157”), which defines fair value, establishes a framework for measuring fair value, and expands disclosures about fair value measurements. This pronouncement applies to other standards that require or permit fair value measurements. Accordingly, this statement does not require any new fair value measurement. The FASB has also issued Staff Position FAS 157-2 (“FSP 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. The Company adopted SFAS 157 on January 1, 2008, for all financial and non-financial assets and liabilities recognized or disclosed at fair value on a recurring basis. The adoption of SFAS 157 did not materially impact the Company’s operating results, financial position or cash flows. The Company elected to defer the application of SFAS 157 to nonfinancial assets and liabilities in accordance with FSP No. 157-2. Non-recurring nonfinancial assets and nonfinancial liabilities for which the Company has not applied the provisions of SFAS 157 include those measured at fair value in impairment testing for unproved properties and asset retirement obligations initially measured at fair value.

     As defined in SFAS 157, fair value is the price that would be received in the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. The Company classifies fair value balances based upon observability of those inputs. SFAS 157 establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (level 1 measurement), pricing inputs are other than quoted prices in active markets, but are either directly or indirectly observable and are valued using models or other valuation methodologies (level 2), and the lowest priority to unobservable inputs (level 3 measurement).

     In February 2007, the FASB issued SFAS No. 159, The Fair Value Option for Financial Assets and Financial Liabilities Including an Amendment of FASB Statement No. 115 (“SFAS 159”), which permits entities to choose to measure many financial instruments and certain other items at fair value (the Fair Value Option). Election of the Fair Value Option is made on an instrument-by-instrument basis and is irrevocable. At the adoption date, unrealized gains and losses on financial assets and liabilities for which the Fair Value Option has been elected would be reported as a cumulative adjustment to beginning retained earnings. If the Company elects the Fair Value Option for certain financial assets and liabilities, the Company will report unrealized gains and losses due to changes in fair value in earnings at each subsequent reporting date. The Company adopted SFAS 159 as of January 1, 2008, and the adoption did not have a material impact on the Company’s operating results, financial position and cash flows as the Company did not elect the Fair Value Option for any of its financial assets or liabilities.

     In April 2007, the FASB issued Staff Position (FSP) No. FIN 39-1, Amendment of FASB Interpretation No. 39, (“FIN 39-1”) to amend FIN 39, Offsetting of Amounts Related to Certain Contracts (“FIN 39”). The terms “conditional contracts” and “exchange contracts” used in FIN 39 have been replaced with the more general term “derivative contracts.” In addition, FIN 39-1 permits the offsetting of recognized fair values for the right to reclaim cash collateral or the obligation to return cash collateral against fair values of derivatives under certain circumstances, such as under master netting arrangements. Additional disclosure is also required regarding a company’s accounting policy with respect to offsetting fair value amounts. The guidance in FIN 39-1 is effective for fiscal years beginning after November 15, 2007, with early application allowed. The effects of initial adoption should be recognized as a change in accounting principle through retrospective application for all periods presented. The Company adopted FIN 39-1 as of January 1, 2008, and there was no impact on the Company’s operating results, financial position and cash flows.

     In December 2007, the FASB issued Statement SFAS No. 141, Business Combinations (“SFAS 141R”), and SFAS No. 160, Accounting and Reporting of Noncontrolling Interest in Consolidated Financial Statements, an amendment of ARB No. 51 (“SFAS 160”). SFAS 141R and SFAS 160 will significantly change the accounting for and reporting of business combination transactions and noncontrolling (minority) interests in consolidated financial statements. SFAS 141R retains the fundamental requirements in Statement 141, Business Combinations, while providing additional definitions, such as the definition of the acquirer in a purchase and improvements in the application of how the acquisition method is applied. SFAS 160 will change the accounting and reporting for minority interests, which will be recharacterized as noncontrolling interests, and classified as a component of equity. These Statements become simultaneously effective January 1, 2009. Early adoption is not permitted. The Company is currently assessing the impact, if any, that the adoption of this pronouncement will have on the Company’s operating results, financial position or cash flows.

     In March 2008, the FASB issued Statement No. 161, Disclosure about Derivative instruments and Hedging Activities – an amendment to FASB Statement No. 133 (“SFAS 161”). The adoption of SFAS 161 is not expected to have an impact on the Company’s consolidated financial statements, other than additional disclosures. SFAS 161 expands interim and annual disclosures about derivative and hedging activities that are intended to better convey the purpose of derivative use and the risks managed. SFAS 161 is effective for fiscal years and interim periods beginning after November 15, 2008.

Note 2 —Debt

     Debt consists of the following:

		As of
		June 30,				December 31,
		2008				2007
		(in thousands)
Revolving Credit Facility		$	9,910				$  22,000
Less current portion			(9,910	)			(22,000	)
Long-term debt		$	—				$         —

Revolving Credit Facility

     On January 10, 2007, the Company entered into a reserve-based revolving credit facility (the “Revolving Credit Facility”) with Amegy. Under the related loan agreement (the “Loan Agreement”) between Infinity, Infinity Oil and Gas of Texas, Inc. and Infinity Oil & Gas of Wyoming, Inc. (each wholly-owned subsidiaries of the Company and together, the “Guarantors”) and Amegy, Infinity could borrow, repay and re-borrow on a revolving basis up to the aggregate sums permitted under the borrowing base, $22,000,000 (reduced to $10,500,000 effective as of August 10, 2007 and subsequently reduced to $3,806,000 effective as of March 26, 2008). The Revolving Credit Facility had an initial term of two years. Amounts borrowed bear interest at prime plus 0.50% (5.5% at June 30, 2008). Interest payments are due on a monthly basis, and principal payments may be required to meet a borrowing base deficiency or monthly borrowing commitment reductions. The borrowing base under the Revolving Credit Facility and the applicable interest rate are subject to adjustment at least once every three months. Amounts borrowed under the Revolving Credit Facility are collateralized by substantially all of the assets of Infinity and its subsidiaries and are guaranteed by Infinity’s subsidiaries. The Revolving Credit Facility contains certain standard continuing covenants and agreements and requires the Company to maintain certain financial ratios and thresholds.

     On August 31, 2007, the Company entered into a Forbearance Agreement, effective as of August 10, 2007, under the Loan Agreement among the Company, the Guarantors, and Amegy. The Forbearance Agreement related to the breach by the Company and Guarantors of: (i) the “Interest Coverage Ratio” set forth in Section 8(a) of the Loan Agreement for the period ended June 30, 2007; (ii) the “Funded Debt to EBITDA Ratio” set forth in Section 8(d) of the Loan Agreement and (iii) the requirement to deliver certain lien releases under Section 9 of the Loan Agreement.

     The Company entered into the Second Forbearance Agreement, under the Revolving Credit Facility as a result of the Company’s failure to meet substantially all financial and certain other covenants during certain periods of 2007. Under this agreement, Amegy agreed to forebear from exercising any remedies under the Revolving Credit Facility, the revolving note and the related loan documents and to temporarily waive the covered events of default through May 30, 2008. The Company was required to repay the borrowing base deficiency by May 30, 2008 through the sale of assets, refinancing of the loan or some other means of raising capital. The Company failed to comply with the terms of the Second Forbearance Agreement and is currently in discussions with Amegy regarding an extension of the forbearance period or a new forbearance agreement; however, we may be unable to reach agreement on these matters at all or on acceptable terms. Amegy is currently entitled to impose a default interest rate (prime plus 6.5%) or to declare an event of default, at which point the entire unpaid principal balance of the loan, together with all accrued and unpaid interest and other amounts then owing to Amegy would become immediately due and payable. Amegy or other creditors may take action to enforce their rights with respect to outstanding obligations, and Infinity may be forced to liquidate. Because substantially all of the Company’s assets are collateral under the Revolving Credit Facility, if Amegy declares an event of default, it would be entitled to foreclose on and take possession of the Company’s assets.

     Infinity has accrued forbearance and additional fees due in connection with the Forbearance Agreements of $1,548,000 through June 30, 2008. 

Senior Secured Notes Facility

     The Company had a senior secured notes facility (the “Senior Secured Notes Facility”) with a group of lenders (collectively, the “Buyers”), under which the Company sold, and the Buyers purchased, on four separate occasions, an aggregate of $53 million principal amount of senior secured notes (the “Notes”) and five-year warrants to purchase an aggregate 5,829,726 shares of the Company’s common stock at an exercise price of $5.00 per share (the “Warrants”). The Notes were repaid in December 2006. All such warrants were outstanding at June 30, 2008.

Note 3 — Stock Options

     Effective January 1, 2006, the Company adopted SFAS No. 123(R), Share-Based Payment, which requires companies to recognize compensation expense for share-based payments based on the estimated fair value of the awards. SFAS No. 123(R) also requires tax benefits relating to the deductibility of increases in the value of equity instruments issued under share-based compensation arrangements that are not included in costs applicable to sales (“excess tax benefits”) to be presented as financing cash inflows in the statement of cash flows. The Company adopted SFAS No. 123(R) using the modified prospective transition method. Under this method, compensation cost recognized is based on the grant-date fair value for all share-based payments granted or modified subsequent to December 31, 2005, estimated in accordance with the provisions of SFAS No. 123(R).

Options Under Employee Option Plans

     In May 2006, the Company’s stockholders approved the 2006 Equity Incentive Plan (the “2006 Plan”), under which both incentive and non-statutory stock options may be granted to employees, officers, non-employee directors and consultants. An aggregate of 470,000 shares of the Company’s common stock are reserved for issuance under the 2006 Plan. Options granted under the 2006 Plan allow for the purchase of common stock at prices not less than the fair market value of such stock at the date of grant, become exercisable immediately or as directed by the Company’s Board of Directors and generally expire ten years after the date of grant. The Company also has other equity incentive plans with terms similar to the 2006 Plan. As of June 30, 2008, 317,000 shares were available for future grants under all plans.

     The fair value of each option award is estimated on the date of grant using the Black-Scholes option-pricing model, which requires the input of subjective assumptions, including the expected term of the option award, expected stock price volatility and expected dividends. These estimates involve inherent uncertainties and the application of management judgment. For purposes of estimating the expected term of options granted, the Company aggregates option recipients into groups that have similar option exercise behavioral traits. Expected volatilities used in the valuation model are based on the expected volatility used by an independent market participant

in the valuation of certain of the Company’s warrants. The risk-free rate for the expected term of the option is based on the U.S. Treasury yield curve in effect at the time of grant. The Company’s forfeiture rate assumption used in determining its stock-based compensation expense is estimated based on historical data and have varied between 0% and 100% during the six months ended June 30, 2008 and 2007. The actual forfeiture rate could differ from these estimates. The following table summarizes the inputs used in the calculation of fair value of options granted during the six months ended June 30, 2008 and 2007:

		Six Months Ended June 30,
		2008				2007
Expected term (in years)			5.5				5.5 – 10.0
Expected stock price volatility			140	%			55% - 61	%
Expected dividends			—				—
Risk-free rate			3.34	%			4.66% - 4.71	%

     The following table summarizes stock option activity as of and for the six months ended June 30, 2008:

						Weighted Average				Aggregate				Weighted Average
						Exercise				Intrinsic Value				Remaining
		Number of Options				Price Per Share				(in thousands)				Contractual Term
Outstanding at January 1, 2008			1,226,500				$   5.42
Granted			550,000				0.38
Forfeited or expired			(247,500	)			4.95
Outstanding at June 30, 2008			1,529,000				3.68				$        -				8.5 years
Exercisable at June 30, 2008			1,529,000				3.68				$        -				8.5 years

     The weighted-average grant-date fair value of options granted during the six months ended June 30, 2008 and 2007 was $0.35 and $2.04, respectively. During the six months ended June 30, 2008 and 2007, the Company recognized compensation expense of $402,000 and $585,000, respectively. The Company did not recognize a tax benefit related to the stock-based compensation recognized during the six months ended June 30, 2008 and 2007, as the Company has a fully reserved deferred tax asset. There was no unrecognized compensation cost as of June 30, 2008, related to unvested stock and stock options.

     The Company received no cash proceeds during the six months ended June 30, 2008 and 2007, respectively, from the exercise of stock options.

Note 4 — Derivative Instruments

Commodity Derivatives

     As of June 30, 2008 the Company had no oil and natural gas derivative arrangements outstanding.

     As of December 31, 2007, the Company had net commodity derivative liabilities of $2,144,000, which are included in accrued liabilities in the accompanying Consolidated Balance Sheets. Effective with the three months ended December 31, 2006, the Company determined it no longer qualified to utilize hedge accounting for its oil and natural gas derivative arrangements. As such, all changes in the derivative’s fair value are recognized currently in earnings. During the six months ended June 30, 2008 and 2007, the Company recognized losses of $109,000 and $1,420,000, respectively, under its swap and collar arrangements, which is reflected in change in derivative fair value in the accompanying Consolidated Statements of Operations. The Company paid $2,236,000 under its arrangements during the six months ended June 30, 2008 and received $145,000 during the six months ended June 30, 2007, respectively. During the six months ended June 30, 2007, the Company reclassified from other comprehensive income to change in derivative fair value, gains of $96,000 related to contracts that had been designated as cash flow hedges but lost effectiveness in 2006.

Other Derivatives

     As discussed in Note 2 above, during 2005 and 2006, the Company issued Notes and Warrants. Under the provisions of SFAS No. 133 and EITF 00-19 the Company bifurcated the conversion option associated with the Notes and accounted for it and the Warrants as derivatives. During the six months ended June 30, 2008 and 2007, the Company recognized other income of $75,000 and $1,069,000, respectively, related to the change in the fair value of the Warrants.

Note 5 — Commitments and Contingencies

Delivery Commitments

     Effective September 2001, Infinity-Wyoming entered into a gas gathering and transportation contract with a third-party gatherer and processor in which the third-party gatherer and processor built gas gathering laterals and installed compression facilities to deliver gas produced from the Pipeline Field to the Overland Trail Transmission pipeline. During the six months ended June 30, 2007, Infinity-Wyoming expensed $623,000 to settle this disputed volume commitment deficiency.

     In June 2005, the Company entered into a long-term gas gathering contract for natural gas production from the Company’s properties in Erath County, Texas, under which the Company pays a gathering fee of $0.35 per Mcf gathered. The contract contains minimum delivery volume commitments through December 31, 2011 associated with firm transportation rights. As of June 30, 2008 and December 31, 2007, the Company had accrued approximately $157,000 and $90,000, respectively, as quarterly delivery commitment shortfalls under the contract.

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     The following information should be read in conjunction with the Unaudited Consolidated Financial Statements and Notes presented elsewhere in this Quarterly Report on Form 10-Q. Infinity follows the full-cost method of accounting for exploration and production activities. See “Nature of Operations” and “Basis of Presentation,” included in Note 1 to the Unaudited Consolidated Financial Statements.

     Infinity and its operating subsidiaries, Infinity-Texas and Infinity-Wyoming, are engaged in identifying and acquiring oil and gas acreage, exploring and developing acquired acreage and oil and gas production, with a focus on the acquisition, exploration and development of and production from its properties in the Fort Worth Basin of north central Texas and Greater Green River, Sand Wash and Piceance Basins of southwest Wyoming and northwest Colorado. Infinity has also been awarded a 1.4 million acre concession offshore Nicaragua in the Caribbean Sea, which it intends to explore over the next few years. The validity of the contracts relating to our concessions, and potentially the concessions themselves, has been challenged and Infinity is currently seeking ratifications of the contracts and concessions.

FORWARD-LOOKING STATEMENTS

     This Quarterly Report on Form 10-Q contains forward-looking statements as defined in the Private Securities Litigation Reform Act of 1995. The use of any statements containing the words “anticipate,” “intend,” “believe,” “estimate,” “project,” “expect,” “plan,” “should” or similar expressions are intended to identify such statement. Forward-looking statements include, among other items:

	•		Infinity’s business strategy and anticipated trends in Infinity’s business and its future results of operations;
	•		Infinity’s ability to continue as a going concern;
	•		Infinity’s ability to obtain an extension of the forbearance period or a new forbearance agreement from Amegy;
	•		Infinity’s ability to repay the significant borrowing base deficiency under the Revolving Credit Facility;
	•		possible requirement and efforts to sell assets of Infinity-Texas;
	•		the timing of anticipated production from wells under the Farmout Agreement in 2008;
	•		the impact of limitations relating to future general and administrative costs on future operations;
	•		the impact of cash flows on future operations;
	•		our need for external financing in 2008 and beyond;
	•		our plans with respect to the exploration and development of our offshore Nicaragua concessions;
	•		our ability to obtain final central government approval for our Nicaragua contract and concessions;
	•		success of the Company’s plans to move forward with exploration in Nicaragua;
	•		our planned capital expenditures in 2008;
	•		commencement and progress of exploration, drilling and completion activities;
	•		availability of drilling rigs and other support equipment;
	•		the connection of Infinity’s wells to third party pipeline systems;
	•		the abandonment of wells and the costs associated therewith;
	•		the availability of financing on acceptable terms;
	•		the impact of governmental regulation;
	•		the timing of engineering and environmental impact studies and permitting;
	•		title to assets and related liens and encumbrances; and
	•		receipt of sufficient rights-of-way grants and permits to operate our business,

     Forward-looking statements inherently involve risks and uncertainties that could cause actual results to differ materially from the
forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to the following and the risks described in “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2007:

	•		covenants and debt service obligations may adversely affect our cash flow and our ability to raise capital;
	•		failure to obtain forbearance or waivers of events of default under the Revolving Credit Facility;
	•		failure to achieve success under the Farmout Agreement;
	•		fluctuations in oil and natural gas prices and production;
	•		inaccurate estimations of required capital expenditures;
	•		uncertainties inherent in estimating quantities of oil and gas reserves and projecting future rates of production and timing of development activities;
	•		operating hazards could result in substantial losses against which we not be adequately insured;
	•		an increase in the cost of oil and gas drilling, completion and production and of materials, fuel and labor costs;
	•		the availability, conditions and timing of required government approvals and third party financing;
	•		a decline in demand for Infinity’s oil and gas production; and
	•		changes in general economic conditions.

2008 Operational and Financial Objectives

     On January 7, 2008, Infinity-Wyoming completed the sale of essentially all of its producing oil and gas properties in Colorado and Wyoming, along with 80% of the working interest owned by the Company in undeveloped leaseholds in Routt County, Colorado and Sweetwater County, Wyoming. Substantially all of Infinity-Wyoming’s remaining undeveloped leaseholds will require additional geological and geophysical analysis prior to identifying and drilling prospective prospects. Infinity-Wyoming anticipates 2008 capital expenditures will be limited and likely less than $0.5 million to plug and abandon and perform reclamation activities on ten to fifteen wells.

     In addition, concurrent with the Infinity-Wyoming sale, Infinity-Texas entered into a Farmout Agreement with Forest relating to certain oil and gas leaseholds owned by it in Erath County, Texas. Forest began drilling two wells in late April 2008 and assuming results are favorable, we would expect to realize the benefits of initial production from those activities beginning in the third or fourth quarters of 2008. Infinity-Texas plans to focus on maintaining its production in the Fort Worth Basin of central Texas. Infinity-Texas anticipates its 2008 capital expenditures will be limited and likely less than $0.5 million to potentially complete two vertical wells awaiting completion at June 30, 2008.

     The Company’s ability to complete these activities is dependent on a number of factors including, but not limited to:

	•		The availability of the capital resources required to fund the activity;
	•		The availability of third party contractors for completion services; and
	•		The approval by regulatory agencies of applications for permits to conduct exploration activities in a timely manner.

     The validity of the contracts relating to our Nicaraguan concessions, and potentially the concessions themselves, has been challenged and Infinity is currently seeking ratifications of the contracts and concessions from Nicaragua’s federal government. Ratifications have been received from the Autonomous Region of the Southern Atlantic Region (“RAAS”) and the Autonomous Region of the Northern Atlantic (“RAAN”). We now only require final review and approval of the contracts by the central government. We remain hopeful that the central government will approve our contracts in a timely manner. Following the receipt of approval from the national government, Infinity plans to conduct an environmental study and the development of geological information from reprocessing and additional evaluation of existing 2-D seismic data to be acquired over the concession blocks offshore Nicaragua. Infinity also intends to seek offers from other industry operators for interests in the acreage in exchange for cash and a carried interest in exploration and development operations. No assurance can be given that any such transactions will be consummated.

Overview of Exploration and Production Activity

     Infinity expects the exploration and development of its Fort Worth Basin acreage and its Rocky Mountain prospects to proceed slowly, due in part to governmental restrictions, limited financial resources, and its requirement to repay the remaining $6.1 million deficiency under the Revolving Credit Facility. In addition to cash flows from operating activities, if any, Infinity will require external financing during the remainder of 2008 and beyond to fund its exploration operations and working capital deficit. Infinity may be unable to obtain such financing on acceptable terms or at all.

          The following table provides statistical information for the three and six months ended June 30, 2008 and 2007:

		For the Three								For the Six
		Months Ended								Months Ended
		June 30,								June 30,
		2008				2007				2008				2007
Production:
Natural gas (MMcf)			105.9				244.3				227.3				473.3
Crude oil (thousands of barrels)			-				17.0				0.3				30.5
Total (MMcfe)			105.9				346.3				228.8				656.3
Financial Data (thousands of dollars):
Total revenue		$	1,286			$	2,533			$	2,486			$	4,632
Production expenses			622				1,262				1,402				3,320
Production taxes			41				166				68				301
Financial Data per Unit ($  per Mcfe):
Total revenue		$	12.14			$	7.31			$	10.87			$	7.05
Production expenses			5.87				3.64				6.12				5.06
Production taxes			0.39				0.48				0.30				0.46

     At June 30, 2008, the full cost ceiling exceeded the carrying value of the Company’s oil and gas properties, based upon a natural gas price of approximately $13.50 per Mcf in effect at that date. A decline in prices received for gas sales or an increase in operating costs or reductions in estimated economically recoverable quantities could result in the recognition of a ceiling write-down of oil and gas properties in a future period.

Results of operations for the three months ended June 30, 2008 compared to the three months ended June 30, 2007

Net Income (Loss)

     Infinity reported a net loss of $0.8 million, or $0.05 per basic and diluted share, in the three months ended June 30, 2008, compared to a net loss of $16.1 million, or $0.90 per basic and diluted share, respectively, in the prior year period. The change between periods was the result of the items discussed below.

Revenue

     Infinity achieved oil and gas revenue of $1.3 million in the three months ended June 30, 2008 compared to $2.5 million in the prior year period. The $1.2 million, or 49%, decrease in revenue consisted of an approximate $1.7 million decrease attributable to lower oil and gas production, offset by a $0.5 million increase in average prices. The decrease in equivalent production was principally the result of production in 2007 from properties sold to Forest in January 2008.

Production expenses and taxes

     Production costs decreased to $0.6 million for the three months ended June 30, 2008, from $1.3 million in the prior year period. Oil and gas production expenses decreased $0.5 million as a result of production costs associated with production in 2007 from properties sold to Forest in January 2008. Oil and gas production taxes decreased $0.1 million during the three months ended June 30, 2008 as a result of production taxes in 2007 associated with properties sold to Forest in January 2008.

General and Administrative Expenses

     General and administrative expenses were relatively unchanged at $0.8 million for the three months ended June 30, 2008 and 2007, respectively. Decreases in 2008 in salaries and related personnel costs were offset by increases in legal expenses associated with the settlement of past-due payables and a decrease in internal costs capitalized to oil and gas properties.

Depreciation, Depletion, Amortization and Accretion

     Depreciation, depletion, amortization and accretion (“DD&A”) expense recognized during the three months ended June 30, 2008 decreased $1.5 million to $0.4 million from $1.9 million in the prior year period. Decreased DD&A in the 2008 period resulted primarily from a 69% decrease in equivalent production during the quarter.

Ceiling Write-Down

     At June 30, 2007, the carrying value of the Company’s oil and gas properties exceeded the full cost ceiling limitation by approximately $15.8 million, based upon a natural gas price of approximately $6.29 per Mcf and an oil price of approximately $62.03 per barrel in effect at that date. In the three months ended June 30, 2008 the Company was not required to recognize any such ceiling write-down.

Other Income (Expense)

     Other expense was $0.3 million in the three months ended June 30, 2008 compared to other income of $1.2 million in the prior year period. The $1.5 million change was principally due to a 2007 change in derivative fair value of $1.2 million and interest expense of $0.3 million in the 2008 period.

Income Tax

     Infinity reflected no net tax benefit in the three months ended June 30, 2008 and 2007. The net loss generated in those periods increased Infinity’s net deferred tax asset. Due to uncertainty as to the ultimate utilization of the Company’s net deferred tax asset, as of June 30, 2008 and 2007, the Company recorded a full valuation allowance for its net deferred tax asset.

Results of operations for the six months ended June 30, 2008 compared to the six months ended June 30, 2007

Net Income (Loss)

     Infinity reported a net loss of $2.1 million, or $0.12 per basic and diluted share, in the six months ended June 30, 2008, compared to a net loss of $19.8 million, or $1.11 per basic and diluted share, in the prior year period. The change between periods was the result of the items discussed below.

Revenue

     Infinity achieved oil and gas revenue of $2.5 million in the six months ended June 30, 2008 compared to $4.6 million in the prior year period. The $2.1 million, or 46%, decrease in revenue consisted of an approximate $3.0 million decrease attributable to lower oil and gas production, offset by a $0.9 million increase in average prices. The decrease in equivalent production was principally the result of production in 2007 from properties sold to Forest in January 2008.

Production expenses and taxes

     Production costs decreased to $1.4 million for the six months ended June 30, 2008, from $3.3 million in the prior year period. Oil and gas production expenses decreased $1.8 million as a result of production costs associated with production in 2007 from properties sold to Forest in January 2008. Oil and gas production taxes decreased $0.2 million during the six months ended June 30, 2008 as a result of production taxes in 2007 associated with properties sold to Forest in January 2008.

General and Administrative Expenses

     General and administrative expenses decreased to $1.6 million in the six months ended June 30, 2008, as compared to $1.7 million for the six months ended June 30, 2007. Decreases in 2008 in salaries and related personnel costs were largely offset by increases in legal expenses associated with the settlement of past-due payables and a decrease in internal costs capitalized to oil and gas properties.

Depreciation, Depletion, Amortization and Accretion

     Depreciation, depletion, amortization and accretion (“DD&A”) expense recognized during the six months ended June 30, 2008 decreased $2.2 million to $0.8 million from $3.0 million in the prior year period. Decreased DD&A in the 2008 period resulted primarily from a 65% decrease in equivalent production during the quarter.

Ceiling Write-Down

     At June 30, 2007, the carrying value of the Company’s oil and gas properties exceeded the full cost ceiling limitation by approximately $15.8 million, based upon a natural gas price of approximately $6.29 per Mcf and an oil price of approximately $62.03 per barrel in effect at that date. In the six months ended June 30, 2008 the Company was not required to recognize any such ceiling write-down.

Other Income (Expense)

     Other expense was $0.7 million in the six months ended June 30, 2008 compared to $0.4 million in the prior year period. The $0.3 million change was principally due to a 2007 charge for change in derivative fair value of $0.4 million and interest expense of $0.8 million in the 2008 period.

Income Tax

     Infinity reflected no net tax benefit in the six months ended June 30, 2008 and 2007. The net loss generated in those periods increased Infinity’s net deferred tax asset. Due to uncertainty as to the ultimate utilization of the Company’s net deferred tax asset, as of June 30, 2008 and 2007, the Company recorded a full valuation allowance for its net deferred tax asset.

Liquidity and Capital Resources

     As reflected in the accompanying Consolidated Statements of Operations, we have had a history of losses. In addition, we have a significant working capital deficit and are currently experiencing substantial liquidity problems. The Company entered into the Second Forbearance Agreement, under the Revolving Credit Facility as a result of the Company’s failure to meet substantially all financial and certain other covenants during certain periods of 2007. Under this agreement, Amegy agreed to forebear from exercising any remedies under the Revolving Credit Facility, the revolving note and the related loan documents and to temporarily waive the covered events of default through May 30, 2008. The Company was required to repay the borrowing base deficiency by May 30, 2008 through the sale of assets, refinancing of the loan or some other means of raising capital. The Company failed to comply with the terms of the Second Forbearance Agreement and is currently in discussions with Amegy regarding an extension of the forbearance period or a new forbearance agreement; however, we may be unable to reach agreement on these matters at all or on acceptable terms. Amegy is currently entitled to impose a default interest rate (prime plus 6.5%) or to declare an event of default, at which point the entire unpaid principal balance of the loan, together with all accrued and unpaid interest and other amounts then owing to Amegy would become immediately due and payable. Amegy or other creditors may take action to enforce their rights with respect to outstanding obligations, and Infinity may be forced to liquidate. Because substantially all of the Company’s assets are collateral under the Revolving Credit Facility, if Amegy declares an event of default, it would be entitled to foreclose on and take possession of the Company’s assets.

     Infinity agreed to pay Amegy forbearance and additional fees in connection with the Forbearance Agreements which totaled $1.5 million at June 30, 2008.

     As a result, the Company has classified all $9.9 million outstanding under the Revolving Credit Facility at June 30, 2008 as a current liability in the accompanying Consolidated Balance Sheets. Amounts borrowed under the Credit Facility bear interest at prime plus 0.50%.

     Concurrent with the sale of assets on January 7, 2008, the Company repaid $11.1 million of principal outstanding under the Revolving Credit Facility, settled commodity derivative liabilities of $2.3 million, settled general and administrative liabilities of approximately $0.7 million and established an escrow account in the amount of $3.7 million to potentially settle exploration and operating liabilities of Infinity-Texas in the amount of approximately $4.8 million. At June 30, 2008, cash and cash equivalents of $0.4 million were designated for the repayment of 2007 trade payables of approximately $0.7 million. The Company plans to continue to negotiate with and seek concessions from its trade creditors in order to satisfy these obligations.

     Due to the uncertainties related to these matters, there exists substantial doubt about the Company’s ability to continue as a going concern. The financial statements do not include any adjustments relating to the recoverability and classification of asset carrying amounts or the amount and classification of liabilities that might result should the Company be unable to continue as a going concern.

     Infinity’s primary sources of liquidity are cash provided by operations, if any, sales of assets and debt and equity financings. Infinity’s primary needs for cash are for the operation, development, production, exploration and acquisition of oil and gas properties and for fulfillment of working capital obligations.

     As of June 30, 2008, the Company had a working capital deficit of $12.3 million, compared to a working capital deficit of $30.2 million at December 31, 2007. The $17.8 million change in working capital is largely the result of the application of the $17.7 million of proceeds from the sale of assets to Forest to the repayment of $12.1 million in debt, the settlement of $2.3 million of commodity derivative liabilities in January 2008, payments to trade creditors of $2.9 million and the $0.4 million increase in designated cash.

     During the six months ended June 30, 2008, cash used in operating activities was $2.7 million, compared to $1.1 million in 2007. During the 2008 period, cash provided by investing activities was $15.3 million, compared to $15.8 million used in investing activities in 2007. Excluding net proceeds of $17.7 million from the sale of the assets in January 2008, cash used in investing activities during the 2008 period was $2.4 million. The decrease in cash used for capital expenditures of $12.5 million was primarily attributable to a decrease in exploration and development capital expenditures resulting from the suspension of exploration and development activities since mid-2007. During the 2008 period, cash used in financing activities was $12.1 million, compared to $16.1 million provided by financing activities during 2007. The net change of $28.2 million was principally due to the repayment of $12.1 million of debt during the 2008 period compared to proceeds of $17.0 million received from borrowings in 2007.

Off-Balance Sheet Arrangement

     The Company has no off-balance sheet arrangements.

Outlook for 2008

     Depending on the availability of capital resources, the availability of third party contractors for drilling and completion services, and satisfaction of regulatory activities, Infinity could incur capital expenditures of approximately $1 million to $1.5 million during the remainder of 2008. Approximate capital expenditures by operating entity are anticipated to be less than $0.5 million by each of Infinity-Texas, Infinity-Wyoming; and Infinity Energy Resources, Inc.

     Depending on the market price for crude oil and natural gas during 2008, the number of wells ultimately drilled under the Farmout Agreement and stabilized production levels from wells expected to be placed on line during 2008 under the Farmout Agreement, Infinity would expect to generate cash flow from operating activities during 2008, after payment of current operating expenses and interest payments under our Revolving Credit Facility of between $0.5 million and $1 million.

     In summary, Infinity believes that it will have up to $1 million available to it in 2008 from cash from operating activities after payment of current operating expenses and interest payments under our Revolving Credit Facility to fund its potentially required 2008 capital expenditures of $1 million to $2 million.

     If cash flow from operating activities is not at levels anticipated, Infinity may seek the forward sale of oil and gas production, partnerships or strategic alliances for the development of its undeveloped acreage, the public or private offering of common or preferred equity or subordinated debt, asset sales, or other joint interest or joint venture opportunities to fund any cash shortfalls, or, because a portion of Infinity’s potential capital expenditures are discretionary, Infinity could decrease to some degree the level of its capital expenditures. There can be no assurance that the Company would be able to consummate any such sale, partnership, alliance, offering or venture at all or on terms acceptable to the Company.

Critical Accounting Policies and Estimates

     Infinity’s Annual Report on Form 10-K for the year ended December 31, 2007, described the accounting policies that management deemed to be critical to the reporting of our financial position and results of operations because either (i) the accounting estimate requires the Company to make assumptions about matters that are highly uncertain at the time the accounting estimate is made, and different estimates could have reasonably been used for the accounting estimate in the current period, or (ii) in management’s judgment changes in the accounting estimate that are reasonably likely to occur from period to period would have a material impact on the presentation of the Company’s financial condition or results of operations. The most significant judgments and estimates used in the preparation of our consolidated financial statements are:

	•		Reserve estimates,
	•		Unproved properties,
	•		Fair value of derivatives,
	•		Asset retirement obligations,
	•		Valuation of tax asset, and
	•		Oil and gas properties, depreciation and full cost ceiling test.

Recent Accounting Pronouncements

     In December 2007, the FASB issued Statement SFAS No. 141, Business Combinations (“SFAS 141R”), and SFAS No. 160, Accounting and Reporting of Noncontrolling Interest in Consolidated Financial Statements, an amendment of ARB No. 51 (“SFAS 160”). SFAS 141R and SFAS 160 will significantly change the accounting for and reporting of business combination transactions and noncontrolling (minority) interests in consolidated financial statements. SFAS 141R retains the fundamental requirements in Statement 141, Business Combinations, while providing additional definitions, such as the definition of the acquirer in a purchase and improvements in the application of how the acquisition method is applied. SFAS 160 will change the accounting and reporting for minority interests, which will be recharacterized as noncontrolling interests, and classified as a component of equity. These Statements become simultaneously effective January 1, 2009. Early adoption is not permitted. The Company is currently assessing the impact, if any, that the adoption of this pronouncement will have on the Company’s operating results, financial position or cash flows.

     In March 2008, the FASB issued Statement No. 161, Disclosure about Derivative instruments and Hedging Activities – an amendment to FASB Statement No. 133 (“SFAS 161”). The adoption of SFAS 161 is not expected to have an impact on the Company’s consolidated financial statements, other than additional disclosures. SFAS 161 expands interim and annual disclosures about derivative and hedging activities that are intended to better convey the purpose of derivative use and the risks managed. SFAS 161 is effective for fiscal years and interim periods beginning after November 15, 2008.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK

Commodity Risk

     Infinity’s major market risk exposure is in the pricing applicable to its oil and gas production. Realized pricing is primarily driven by the prevailing price for crude oil and natural gas spot prices applicable to Infinity’s crude oil and natural gas production. Historically, prices received for gas production have been volatile and unpredictable. Pricing volatility is expected to continue. Gas price realizations ranged from a low of $9.14 to a high of $13.61 per Mcf during the six months ended June 30, 2008. Oil price realizations ranged from a low of $86.45 per barrel to a high of $101.38 per barrel during that period.

     Infinity periodically enters into fixed-price physical contracts and commodity derivative contracts on a portion of its projected natural gas and crude oil production in accordance with its Energy Risk Management Policy. These activities are intended to support cash flow at certain levels by reducing the exposure to oil and gas price fluctuations.

     Infinity periodically enters into fixed-price physical contracts and commodity derivative contracts on a portion of its projected natural gas and crude oil production in accordance with its Energy Risk Management Policy. These activities are intended to support cash flow at certain levels by reducing the exposure to oil and gas price fluctuations.

     As of June 30, 2008 the Company had no crude oil and natural gas derivative arrangements outstanding.

Interest Rate Risk

     Infinity’s exposure to changes in interest rates results from our $9.9 million in floating rate debt at June 30, 2008. The result of a 10% fluctuation in the prime rate would impact our interest expense, before capitalization, by less than $0.1 million per year.

ITEM 4. CONTROLS AND PROCEDURES

     The Company maintains disclosure controls and procedures that are designed to ensure that information required to be disclosed in the Company’s reports under the Securities Exchange Act of 1934, as amended (“Exchange Act”) is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to management, including the Company’s Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. The Company’s management, with the participation of the Company’s Chief Executive Officer and the Chief Financial Officer, has evaluated the effectiveness of the Company’s disclosure controls and

procedures as of the end of the fiscal quarter covered by this Quarterly Report on Form 10-Q. The Company’s Chief Executive Officer and Chief Financial Officer have concluded that, as of the end of the period covered by this Quarterly Report on Form 10-Q, the Company’s disclosure controls and procedures were effective.

     No changes in internal controls over financial reporting occurred during the second quarter of 2008 that materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting. The Company anticipates that the loss of certain accounting personnel in the third quarter of 2008 may materially affect the Company’s internal control over financial reporting in future periods, and the Company plans to monitor these personnel changes and work to maintain the effectiveness of our internal controls.

PART II

ITEM 1. LEGAL PROCEEDINGS

     There were no material developments in the material litigation in which the Company is currently involved as set forth in our Annual Report on Form 10-K for the year ended December 31, 2007, other than the settlement of all matters associated with BJ Services, U.S.A., Sequoia Fossils Fuel Corp. and Bronco Drilling Company, Inc.

ITEM 1A. RISK FACTORS

     There have been no material changes to our risk factors compared to those provided in our Annual Report on Form 10-K for the year ended December 31, 2007.

ITEM 2. UNREGISTERED SALE OF EQUITY SECURITIES AND USE OF PROCEEDS

     None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

     The Loan Agreement with Amegy contains certain standard continuing covenants and agreements and requires Infinity to maintain certain financial ratios and thresholds. In March 2008, the Company entered into the Second Forbearance Agreement under the Revolving Credit Facility as a result of the Company’s failure to meet substantially all financial and certain other covenants during 2007. The Company has also failed to meet these covenants during 2008, and failed to comply with the terms of the Second Forbearance Agreement. The company is currently in discussions with Amegy regarding an extension to the forbearance period or a new forbearance agreement; however we may be unable to reach an agreement on these matters at all or on acceptable terms.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

     None.

ITEM 5. OTHER INFORMATION

     None.

ITEM 6. EXHIBITS

     (c) Exhibits.

31.1		Certification of Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2		Certification of Principal Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32		Certification of Principal Executive Officer and Principal Financial Officer pursuant to 18 U.S.C. 1350 (Section 906 of the Sarbanes-Oxley Act)

SIGNATURES

     In accordance with the requirements of the Exchange Act, the Registrant caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

Signature		Capacity		Date
/s/ Stanton E. Ross		Chief Executive Officer		August 15, 2008
Stanton E. Ross		(Principal Executive Officer)
/s/ Daniel F. Hutchins		Chief Financial Officer		August 15, 2008
Daniel F. Hutchins		(Principal Financial and Accounting Officer)

Index of Exhibits

31.1		Certification of Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2		Certification of Principal Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32		Certification of Principal Executive Officer and Principal Financial Officer pursuant to 18 U.S.C. 1350 (Section 906 of the Sarbanes-Oxley Act)