AMERICAN NOBLE GAS, INC. - Quarter Report: 2007 March (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 March 31, 2007

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)

Securities registered pursuant to Section 12(b) of the Act: Common Stock

Securities registered pursuant to Section 12(g) of the Act: None

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

Large accelerated filer o          Accelerated filer þ          Non-accelerated filer o

     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 May 10, 2007, 17,871,157 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			15
Item 3. Quantitative and Qualitative Disclosures About Market Risk			22
Item 4. Controls and Procedures			23
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

(in thousands, except share and per share amounts)

		March 31,				December 31,
		2007				2006
ASSETS
Current assets:
Cash and cash equivalents		$	213			$	872
Accounts receivable			1,158				1,511
Prepaid expenses and other			373				719
Prepaid severance taxes			706				609
Total current assets			2,450				3,711
Property and equipment, at cost, net of accumulated depreciation			80				94
Oil and gas properties, using full cost accounting, net of accumulated depreciation, depletion and amortization and ceiling write-down:
Proved			25,733				24,581
Unproved			27,917				26,803
Intangible assets, at cost, net of accumulated amortization			810				59
Other assets, net			1,084				1,056
Total assets		$	58,074			$	56,304
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Note payable		$	36			$	48
Accounts payable			2,098				7,832
Accrued liabilities			2,674				2,775
Current portion of asset retirement obligations			636				466
Total current liabilities			5,444				11,121
Long-term liabilities:
Production taxes payable and other			485				535
Asset retirement obligations, less current portion			1,001				1,136
Derivative liabilities			7,056				5,895
Long-term debt			10,000				—
Total liabilities			23,986				18,687
Commitments and contingencies
Stockholders’ equity:
Preferred stock, par value $.0001, authorized 10,000,000 shares, issued and outstanding -0- (2007)  and -0- (2006) shares			—				—
Common stock, par value $.0001, authorized 75,000,000 shares, issued and outstanding 17,871,157 (2007) and 17,866,157 (2006) shares			2				2
Additional paid-in-capital			78,626				78,303
Accumulated other comprehensive income			46				118
Accumulated deficit			(44,586	)			(40,806	)
Total stockholders’ equity			34,088				37,617
Total liabilities and stockholders’ equity		$	58,074			$	56,304

See Notes to Unaudited Consolidated Financial Statements.

INFINITY ENERGY RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

		For the Three Months
		Ended March 31,
		2007				2006
Revenue
Oil and gas sales		$	2,099			$	2,364
Operating expenses
Oil and gas production expenses			2,058				1,143
Oil and gas production taxes			135				201
General and administrative expenses			964				782
Depreciation, depletion, amortization and accretion			1,133				1,285
Ceiling write-down of oil and gas properties			—				9,100
Operating loss			(2,191	)			(10,147	)
Other income (expense)
Financing costs:
Interest expense, net of capitalization			—				(773	)
Amortization of loan discount and costs, net			—				(440	)
Early extinguishment of debt			—				(122	)
Change in derivative fair value			(1,574	)			(3,460	)
Other			(15	)			244
Total other expense			(1,589	)			(4,551	)
Net loss from continuing operations			(3,780	)			(14,698	)
Income from discontinued operations			—				3,393
Net loss		$	(3,780	)		$	(11,305	)
Basic and diluted net loss loss per share:
Net loss from continuing operations		$	(0.21	)		$	(1.06	)
Income from discontinued operations			—				0.24
Net loss		$	(0.21	)		$	(0.82	)
Weighted average shares outstanding (basic and diluted)			17,871				13,824

See Notes to Unaudited Consolidated Financial Statements.

INFINITY ENERGY RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY

(UNAUDITED)

(in thousands, except share amounts)

										Additional								Accumulated Other				Total
		Common Stock								Paid-In				Accumulated				Comprehensive				Stockholders’
		Shares				Amount				Capital				Deficit				Loss				Equity
Balance, December 31, 2006			17,866,157			$	2			$	78,303			$	(40,806	)		$	118			$	37,617
Issuance of common stock			5,000				—				—				—				—				—
Stock-based compensation			—				—				323				—				—				323
Comprehensive loss:
Net loss			—				—				—				(3,780	)			(3,780	)			(3,780	)
Reclassifications																			(72	)			(72	)
Comprehensive loss																		$	(3,852	)
Balance, March 31, 2007			17,871,157			$	2			$	78,626			$	(44,586	)		$	46			$	34,088

See Notes to Unaudited Consolidated Financial Statements.

INFINITY ENERGY RESOURCES, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)

(in thousands)

		For the Three Months
		Ended March 31,
		2007				2006
Cash flows from operating activities:
Net loss		$	(3,780	)		$	(11,305	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion, amortization and accretion			1,133				1,564
Ceiling write-down of oil and gas properties			—				9,100
Amortization of loan discount and costs			—				440
Non-cash early extinguishment of debt			—				122
Current interest expense settled by stock issuance, net of amounts capitalized			—				37
Non-cash stock-based compensation expense			323				—
Change in fair value of derivative instruments			109				3,460
Unrealized loss on commodity derivative instruments			1,532				57
Gain on sales of assets			—				(294	)
Change in operating assets and liabilities:
Decrease in accounts receivable			352				6
(Increase) decrease in prepaid expenses and other			(102	)			104
Increase (decrease) in accounts payable and accrued liabilities			(3,880	)			356
Net cash (used in) provided by operating activities			(4,313	)			3,647
Cash flows from investing activities:
Capital expenditures – exploration and production			(5,469	)			(11,204	)
Capital expenditures – oilfield services			—				(1,816	)
Proceeds from sale of fixed assets — corporate			—				62
Increase in other assets			—				(54	)
Net cash used in investing activities			(5,469	)			(13,012	)
Cash flows from financing activities:
Net proceeds from borrowings on long-term debt			10,000				8,000
Proceeds from issuance of common stock			—				22
Debt and equity issuance costs			(865	)			(313	)
Repayment of notes payable			(12	)			(168	)
Net cash provided by financing activities			9,123				7,541
Net decrease in cash and cash equivalents			(659	)			(1,824	)
Cash and cash equivalents, beginning of period			872				7,942
Cash and cash equivalents, end of period		$	213			$	6,118

See Notes to Unaudited Consolidated Financial Statements.

INFINITY ENERGY RESOURCES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

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 in Nicaragua.

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. Certain prior period amounts in the accompanying unaudited consolidated financial statements have been reclassified to conform to the current year presentation.

     On December 15, 2006, the Company sold its oilfield services subsidiaries, Consolidated Oil Well Services, Inc. and CIS Oklahoma, Inc. (collectively “Consolidated”) to Q Consolidated Oil Well Services, LLC for approximately $52 million in cash. As a result, Consolidated’s results of operations have been presented as discontinued operations in the accompanying unaudited statements of operations. Included in income from discontinued operations in the accompanying statements of operations for the three months ended March 31, 2007 and 2006 are revenue of $0 and $8,450,000, respectively.

     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 months ended March 31, 2007 are not necessarily indicative of the results that may be expected for the year ending December 31, 2007. The accompanying unaudited consolidated financial statements should be read in conjunction with Infinity’s audited consolidated financial statements for the year ended December 31, 2006.

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 and dry holes) 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 internal costs of $202,000 and $252,000 during the three months ended March 31, 2007 and 2006, 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 future development costs and estimated asset retirement costs, are amortized over total estimated proved reserve quantities. The costs of wells in progress and unevaluated properties, including 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. Abandonment 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 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 designated as cash flow hedges but excluding the future cash outflows associated with settling asset retirement obligations that have been accrued on the balance sheet, using 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 March 31, 2007, the full cost ceiling exceeded the carrying value of the Company’s oil and gas properties, based upon a natural gas price of approximately $6.00 per Mcf and an oil price of approximately $59.00 per barrel in effect at that date. A decline in prices received for oil and 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. In the three months ended March 31, 2006 the Company recognized a ceiling write-down of $9,100,000.

     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
		March 31,				December 31,
		2007				2006
		(in thousands)
Proved oil and gas properties		$	104,166			$	101,920
Unproved oil and gas properties			27,917				26,803
Total			132,083				128,723
Less accumulated depreciation, depletion, amortization and ceiling write-downs			(78,433	)			(77,339	)
Net capitalized costs		$	53,650			$	51,384

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 March 31, 2007 and December 31, 2006, the Company had recorded a full valuation allowance for its net deferred tax asset. During the three months ended March 31, 2007, the Company paid $500,000 in income taxes accrued in 2006 in connection with the gain on sale of discontinued operations.

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 months ended March 31, 2007 related to the effective portion of commodity derivative instruments.

Prepaid Severance Taxes

     At March 31, 2007, the Company had approximately $706,000 recorded as prepaid severance taxes related to estimated production tax refunds from the State of Texas. The estimated refunds result from the June 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.

Other Assets, Net

     At March 31, 2007, other assets include approximately $852,000 of cash on deposit at a bank to secure two letters of credit. The letters of credit were issued to the Instituto Nicaraguense de Energia in connection with the Company’s May 2006 execution of exploration and production contracts for two oil and gas concessions in the Caribbean Sea of Nicaragua and the Company’s requirement under the contracts to incur capital costs of a similar amount during the first sub-period of the contracts.

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 three months ended March 31, 2007 and 2006:

		2007				2006
		(in thousands)
Asset retirement obligations at beginning of period		$	1,602			$	1,413
Accretion expense			24				28
Liabilities incurred			11				10
Liabilities settled			—				—
Revisions of estimates			—				—
Asset retirement obligations at end of period			1,637				1,451
Less: current portion of asset retirement obligations			(636	)			(288	)
Asset retirement obligations, less current portion		$	1,001			$	1,163

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. Interest costs capitalized in the three months ended March 31, 2007 and 2006 were $165,000 and $552,000, respectively.

Intangible Assets

     Intangible assets consist of deferred loan costs, which are amortized over the term of the related debt instrument using the effective interest method. During the three months ended March 31, 2007 and 2006, the Company recorded amortization of deferred loan costs of $114,000 and $181,000, respectively. 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 months ended March 31, 2007 and 2006 were $114,000 and $74,000, respectively.

Fair Value of Financial Instruments

     The carrying value of the Company’s cash, accounts receivable, accounts payable and accrued liabilities represents the fair value of the accounts. The carrying value of debt at March 31, 2007 is estimated to approximate fair value. The fair value of the Company’s derivative liabilities, all of which relate to the Commodity Derivatives and Warrants, is estimated using various models and assumptions related to the estimated term of the instruments, volatility of the price of the Company’s common stock, interest rates and the probability of conversion, redemption or exercise, among other items.

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 months ended March 31, 2007 and 2006, all of the Company’s common stock equivalents were anti-dilutive. Therefore, the impact of 8,862,000 and 5,960,747 common sock equivalents outstanding as of March 31, 2007 and 2006, respectively, were not included in the calculation of diluted loss per share because their effect was anti-dilutive.

Recent Accounting Pronouncements

     In June 2006, the Financial Accounting Standards Board (“FASB”) issued FASB Interpretation Number 48 (“FIN 48”), Accounting for Uncertainty in Income Taxes – an Interpretation of FASB Statement No. 109. This interpretation clarifies the accounting for uncertainty in an enterprise’s financial statements in accordance with SFAS No. 109, Accounting for Income Taxes. This statement prescribes a recognition threshold and measurement of a tax position taken or expected to be taken in a tax return. This interpretation also provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure and transition. The adoption of FIN 48 by the Company on January 1, 2007, had no impact on its financial position or results of operations.

     In September 2006, the FASB issued SFAS No. 157, Fair Value Measurements. The standard provides guidance for using fair value to measure assets and liabilities. Under the standard, fair value refers to the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants in the market in which the reporting entity transacts. The standard clarifies the principle that fair value should be based on the assumptions market participants would use when pricing the asset or liability. In support of this principle, the standard establishes a fair value hierarchy that prioritizes the information used to develop those assumptions. The statement is effective for financial statements issued for fiscal years beginning after November 15, 2007, and interim periods within those fiscal years. The Company is currently evaluating the statement to determine what impact, if any, it will have on the Company.

     In December 2006, the FASB issued FASB Staff Position (“FSP”) No. EITF 00-19-2, Accounting for Registration Payment Arrangements, which addresses an issuer’s accounting for registration payment arrangements. The FSP specifies that the contingent obligation to make future payments or otherwise transfer consideration under a registration payment arrangement, whether issued as a separate agreement or included as a provision of a financial instrument or other agreement, should be separately recognized and

measured in accordance with FASB Statement No. 5, Accounting for Contingencies. The guidance in the FSP amends FASB Statements No. 133, Accounting for Derivative Instruments and Hedging Activities, and No. 150, Accounting for Certain Financial Instruments with Characteristics of both Liabilities and Equity, and FASB Interpretation No. 45, Guarantor’s Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness of Others, to include scope exceptions for registration payment arrangements. The FSP further clarifies that a financial instrument subject to a registration payment arrangement should be accounted for in accordance with other applicable generally accepted accounting principles without regard to the contingent obligation to transfer consideration pursuant to the registration payment arrangement. FSP No. EITF 00-19-2 was effective immediately for registration payment arrangements and the financial instruments subject to those arrangements that are entered into or modified subsequent to the date of issuance of the FSP. The adoption of FSP No. EITF 00-19-2 by the Company on January 1, 2007, had no material impact on its financial position or results of operations.

     During 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. The standard permits an entity to make an irrevocable election to measure most financial assets and financial liabilities at fair value. The fair value option may be elected on an instrument-by-instrument basis, with a few exceptions, as long as it is applied to the instrument in its entirety. Changes in fair value would be recorded in income. SFAS No. 159 established presentation and disclosure requirements intended to help financial statement users understand the effect of the entity’s election on earnings. SFAS No. 159 is effective as of the beginning of the first fiscal year beginning after November 15, 2007. Early adoption is permitted. The Company is currently evaluating the statement to determine what impact, if any, it will have on the Company.

Note 2 —Debt

     Debt consists of the following:

		As of
		March 31,				December 31,
		2007				2006
		(in thousands)
Revolving Credit Facility		$	10,000			$	—
Other			36				48
			10,036				48
Less current portion			(36	)			(48	)
Long-term debt		$	10,000			$	—

Revolving Credit Facility

     On January 10, 2007, the Company entered into a $50 million reserve-based revolving credit facility (the “Revolving Credit Facility”) with Amegy Bank N.A. (“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. and Amegy, Infinity may borrow, repay and re-borrow on a revolving basis up to the lesser of (i) the aggregate sums permitted under the borrowing base, initially set at $27 million, or (ii) $50 million. As of May 4, 2007, the Company had drawn $12.2 million under the Revolving Credit Facility. The Revolving Credit Facility has an initial term of two years. Amounts borrowed bear interest at graduated variable rates based on LIBOR or the prime rate, which rates shall be adjusted based on the percentage of the applicable borrowing base used by Infinity from time to time. LIBOR rates can range between LIBOR plus 2.50% and LIBOR plus 3.25%, and prime rates can range between prime and prime plus 0.50% (7.86% at March 31, 2007). 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 six 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. The Company failed to meet certain of these financial covenants during the three months ended March 31, 2007. Amegy has subsequently waived the violation of those covenants for the three months then ended.

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, and 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 a weighted average exercise price of $5.00 per share (the “Warrants”). All such warrants were outstanding at March 31, 2007.

     The outstanding principal amount of Notes and accrued interest of approximately $49.2 million was repaid on December 15, 2006 with proceeds from the sale of the Company’s oilfield service business and the Senior Secured Notes Facility was terminated.

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 March 31, 2007, 917,381 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. 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 three months ended March 31, 2007 and 2006:

		Three Months Ended March 31,
		2007				2006
Expected term (in years)			5.5				n/a
Expected stock price volatility			55	%			n/a
Expected dividends			—				—
Risk-free rate			4.66	%			n/a
Forfeiture rate			50	%			—

     The following table summarizes stock option activity as of and for the three months ended March 31, 2007:

						Weighted Average				Aggregate				Weighted Average
						Exercise				Intrinsic Value				Remaining
		Number of Options				Price Per Share				(in thousands)				Contractual Term
Outstanding at January 1, 2007			1,021,000			$	6.58
Granted			40,000				3.18
Exercised			—				—
Forfeited			(129,000	)			6.44
Outstanding at March 31, 2007			932,000				6.45			$	—			7.8 years
Exercisable at March 31, 2007			607,000				6.80			$	—			7.0 years

     The weighted-average grant-date fair value of options granted during the three months ended March 31, 2007 was $3.18. There were no stock-based awards granted during the three months ended March 31, 2006. During the three months ended March 31, 2007, the Company recognized compensation expense of approximately $323,000. The Company did not recognize a tax benefit related to the stock-based compensation recognized during the three months ended March 31, 2007 and 2006 as the Company has a fully reserved deferred tax asset. Unrecognized compensation cost of $306,000 as of March 31, 2007, related to unvested stock and stock options will be recognized over the next ten months.

     The Company received $0 and $22,000 cash proceeds during the three months ended March 31, 2007 and 2006, respectively, from the exercise of stock options. The total intrinsic value of options exercised during the three months ended March 31, 2006 was approximately $16,000.

Note 4 — Derivative Instruments

Commodity Derivatives

     As of March 31, 2007 the Company had the following oil swap and collar derivative arrangements outstanding:

						NYMEX				NYMEX				NYMEX
Term of Arrangements		Bbls per Day				Swap Price				Floor Price				Ceiling Price
April 1, 2007 — June 30, 2007			50							$	57.50			$	77.50
April 1, 2007 — September 30, 2007			50							$	60.00			$	85.50
July 1, 2007 — December 31, 2007			50							$	62.50			$	87.00
October 1, 2007 — March 31, 2008			50							$	62.00			$	85.60
April 1, 2008 — December 31, 2008			65			$	57.40
January 1, 2009 — December 31, 2009			55			$	57.95
January 1, 2010 — December 31, 2010			50			$	58.90

     As of March 31, 2007 the Company had the following natural gas swap and collar derivative arrangements outstanding:

		MMBtu				WAHA				WAHA				WAHA
Term of Arrangements		per Day				Swap Price				Floor Price				Ceiling Price
April 1, 2007 — June 30, 2007			1,000							$	6.00			$	10.55
July 1, 2007 — September 30, 2007			1,000							$	6.50			$	10.20
October 1, 2007 — December 31, 2007			1,000			$	6.915
January 1, 2008 — December 31, 2008			800			$	7.235
January 1, 2009 — December 31, 2009			600			$	7.170
January 1, 2010 — December 31, 2010			500			$	6.865

		MMBtu				CIG - RM
Term of Arrangement		per Day				Swap Price
April 1, 2007 — December 31, 2007			600			$	5.200
January 1, 2008 — December 31, 2008			400			$	6.475
January 1, 2009 — December 31, 2009			400			$	6.810
January 1, 2010 — December 31, 2010			300			$	6.565

     As of March 31, 2007 and December 31, 2006, the Company had commodity derivative (liabilities) assets of $(1,242,000) and $363,000, respectively, which are included in prepaid expenses and other, other assets, accrued liabilities, or derivative liabilities in the accompanying Consolidated Balance Sheets. During 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 derivatives’ fair value are recognized currently in earnings. During the three months ended March 31, 2007 and 2006, the Company recognized unrealized losses of $1,604,000 and $57,000, 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 received (paid) $67,000 and $(2,000) under its collar arrangements during the three months ended March 31, 2007 and 2006, respectively. During the three months ended March 31, 2007, the Company reclassified from other comprehensive income to change in derivative fair value, gains of approximately $72,000 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 three months ended March 31, 2007 and 2006, the Company recognized charges of $0 and $57,000, respectively, related to the change in the fair value of the Conversion Option and approximately $109,000 and $2,357,000, respectively, related to the change in the fair value of the Warrants.

Note 5 — Commitments and Contingencies

Delivery Commitments

     Effective September 2001, the Company entered into a five-year gas gathering and transportation contract with a third-party gatherer and processor. The Company was to pay a gathering fee of approximately $0.40 per Mcf until 7.5 Bcf of natural gas was produced at which time the fee is to be reduced to $0.25 per Mcf. Through September 30, 2006, the Company delivered approximately 4.4 Bcf under this contract, a shortfall of 3.1 Bcf. The Company accrued $623,000 during the three months ended March 31, 2007 to settle this dispute.

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 oil and gas properties. See “Nature of Operations” and “Basis of Presentation,” included in Note 1 to the Unaudited Consolidated Financial Statements.

     Infinity and its operating subsidiaries (Infinity Oil and Gas of Texas, Inc. (“Infinity-Texas”) and Infinity Oil & Gas of Wyoming, Inc. (“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 the Greater Green River, Sand Wash and Piceance Basins of southwest Wyoming and northwest Colorado; and (ii) providing oilfield services in the mid-continent region and the Powder River and Big Horn Basins of northern Wyoming. 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.

     On December 15, 2006, Infinity sold its oilfield services business for approximately $52 million. Infinity has reflected the results its oilfield services business as discontinued operations in its statements of operations and balance sheet. The Company’s discussion in Management’s Discussion and Analysis is presented on a continuing operations basis.

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;
	•		the ability of Infinity to make and integrate acquisitions;
	•		the financing of exploration and development operations for our offshore Nicaragua property;
	•		commencement and progress of exploration, drilling and completion activities;
	•		availability of drilling rigs, completion services and other support equipment;
	•		the connection of Infinity’s wells to third party pipeline systems;
	•		the costs and results of dewatering operations, including drilling water disposal wells;
	•		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;
	•		receipt of sufficient rights-of-way grants and permits to operate our business; and
	•		the impact of cash flows on future operations.

     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, 2006:

	•		fluctuations in oil and natural gas prices and production;
	•		hedging transactions may limit our potential gains or expose us to losses;
	•		inaccurate estimations of required capital expenditures;
	•		covenants and debt service obligations may adversely affect our cash flow and our ability to raise capital;
	•		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 may not be insured;
	•		an increase in the cost of oil and gas drilling, completion and production and in 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.

2007 Operational and Financial Objectives

Exploration and Production

     Infinity-Wyoming plans to focus on optimizing production from existing wells and advancing of its prospects through additional geological and geophysical analysis. Infinity-Wyoming anticipates its remaining 2007 capital expenditures will be less than $1 million to reenter and recomplete a gas well previously abandoned by another operator, conduct additional geological and geophysical analysis, increase its acreage positions, and plug and abandon certain wells drilled during 2000 through 2002.

     Infinity-Texas plans to focus on increasing its production and acreage position in the Fort Worth Basin of north central Texas. Infinity-Texas anticipates its remaining 2007 capital expenditures will be approximately $15 million to $18 million to drill between seven and twelve wells, complete three wells in progress at March 31, 2007, conduct additional geological and geophysical analysis on its acreage and acquire additional acreage. At March 31, 2007, Infinity-Texas had one horizontal well drilling, and one horizontal well and one vertical well waiting completion operations.

     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 drilling rigs and completion services (although the Company has one rig under contract and operating in Texas); and
	•		The approval by regulatory agencies of applications for permits to conduct exploration activities in a timely manner.

Corporate Activities

     Infinity plans to conduct an environmental study and to develop geological information from the reprocessing and additional evaluation of existing 2-D seismic data to be acquired over its Perlas and Tyra concession blocks offshore Nicaragua. Infinity has issued letters of credit totaling approximately $850,000 for this initial work on the leases.

Overview of Exploration and Production Activity

     Infinity, through Infinity-Texas, continued to expand its exploration and production operations in the Fort Worth Basin of Texas. During the three months ended March 31, 2007, Infinity-Texas drilled one horizontal well and commenced the drilling of a second horizontal well targeting the Barnett Shale formation; increased production from the Fort Worth Basin in north central Texas by approximately 30% as compared to the three months ended March 31, 2006 and continued its seismic interpretation and leasing activities.

     Infinity expects to continue to explore and develop its Fort Worth Basin acreage and its Rocky Mountain prospects. Infinity expects its Rocky Mountain projects to proceed more slowly, due in part to governmental restrictions. Infinity raised incremental capital to fund its exploration and production operations from the net proceeds of the Revolving Credit Facility during the first three months of 2007. In addition to expected increases in cash flows from operating activities, Infinity will require external financing during 2007 and beyond to fund its exploration operations. The type, timing, cost and amounts of such financing, if any, will depend upon general energy and capital markets conditions and the success of Infinity’s operations.

     During the three months ended March 31, 2007, Infinity-Wyoming acquired and began to reprocess and evaluate previously existing 2-D seismic over its Sand Wash and Piceance prospects and partially deepened one of its existing oil wells.

     The following table provides statistical information for the three months ended March 31, 2007 and 2006:

		For the Three
		Months Ended
		March 31,
		2007				2006
Production:
Natural gas (MMcf)			229.0				207.0
Crude oil (thousands of barrels)			13.5				18.8
Total (MMcfe)			310.0				319.5
Financial Data (thousands of dollars):
Total revenue		$	2,099			$	2,364
Production expenses			2,058				1,143
Production taxes			135				201
Financial Data per Unit ($  per Mcfe):
Total revenue		$	6.77			$	7.40
Production expenses			6.64				3.58
Production taxes			0.44				0.63

Results of operations for the three months ended March 31, 2007 compared to the three months ended March 31, 2006

Net Income (Loss)

     Infinity reported a net loss of $3.8 million, or $0.21 per basic and diluted share, in the three months ended March 31, 2007 compared to a net loss of $11.3 million, or $0.82 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 $2.1 million in the three months ended March 31, 2007 compared to $2.4 million in the prior year period. The $0.3 million, or 11%, decrease in revenue consisted of an approximate $0.2 million decrease attributable to lower average prices and $0.1 million decrease attributable to lower oil and gas equivalent production. The decrease in average price was principally attributable to a 31% decrease in the price received for oil sold in northwest Colorado in 2007 as compared to the 2006 period. This decrease in the price of oil corresponded to a regional decrease in the demand for oil due to significant maintenance projects conducted at several local refineries during the period. The decrease in equivalent production was primarily the result of a 30% decrease in oil volumes produced by the Company in northwest Colorado as a result of decreased demand and the temporary cessation of production from the Wolf Mountain 15-2-7-87 well following the production equipment fire suffered on March 15, 2007, partially offset by increases in natural gas production from wells in the Fort Worth Basin. The Wolf Mountain 15-2-7-87 well was successfully returned to production on April 12, 2007 and the Company has entered into a new oil sales contract effective with May 1,

2007 sales that would have yielded an approximate 16% improvement in Colorado oil prices had it been in place during the three months ended March 31, 2007.

Production expenses and taxes

     Production costs increased to $2.2 million for the three months ended March 31, 2007, from $1.3 million in the prior year period. Oil and gas production expenses increased $0.9 million primarily as a result of a $0.6 million accrual for the settlement of volume deficiencies during 2003 through 2006 under a natural gas delivery commitment contract at the Company’s field in Sweetwater County, Wyoming, significantly higher well workover costs on projects deferred from the second-half of 2006, and repair and maintenance costs associated with the production equipment fire on the Wolf Mountain 15-2-7-87 well. Oil and gas production taxes decreased to $0.1 million for the three months ended March 31, 2007, compared to $0.2 million for the 2006 period. The decrease principally reflects the June 2006 designation of the Barnett Shale in Erath County, Texas as a tight gas formation eligible for a reduced production tax rate.

General and Administrative Expenses

     General and administrative expenses increased to $1.0 million for the three months ended March 31, 2007, from $0.8 million in the prior year period. The increase was attributable to non-cash stock-based compensation expense of $0.3 million recorded in the 2007 period as compared to no such expense in the 2006 period, partially offset by decreases in personnel and personnel related costs.

Depreciation, Depletion, Amortization and Accretion

     Depreciation, depletion, amortization and accretion (“DD&A”) expense recognized during the three months ended March 31, 2007 decreased $0.2 million to $1.1 million from $1.3 million in the prior year period. Decreased DD&A in the 2007 period resulted from a decrease in the Company’s oil and gas properties subject to depletion as of March 31, 2007, and a 3% decrease in equivalent production during the quarter.

Ceiling Write-Down

     At March 31, 2007, the full cost ceiling exceeded the carrying value of the Company’s oil and gas properties, based upon a natural gas price of approximately $6.00 per Mcf and an oil price of approximately $59.00 per barrel in effect at that date. A decline in prices received for oil and 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. In the three months ended March 31, 2006 the Company recognized a ceiling write-down of $9.1 million.

Other Income (Expense)

     Other expense of $1.6 million in the three months ended March 31, 2007 decreased compared to other expense of $4.6 million in the prior year period. The decrease of $3.0 million was principally due to a $1.9 million decrease in the charge for change in derivative fair value and a $1.3 million decrease in financing costs recorded in 2006 in connection with the Company’s senior secured notes which were retired in December 2006, partially offset by a $0.3 million decrease in other income.

Income Tax

     Infinity reflected no net tax benefit or expense in the three months ended March 31, 2007 and 2006. The net operating losses 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 March 31, 2007 and 2006, the Company recorded a full valuation allowance for its net deferred tax asset.

Discontinued Operations

     On December 15, 2006, the Company completed the sale of its oilfield services subsidiaries for approximately $52 million in cash. Results from the Company’s oilfield subsidiaries are reflected as discontinued operations for all periods. Included in income from discontinued operations for the three months ended March 31, 2006 is revenue and pretax income of $8.5 million and $3.4 million, respectively.

Liquidity and Capital Resources

     Infinity’s primary sources of liquidity are expected to be cash provided by operations and debt and equity financing. Infinity’s primary needs for cash are for the operation, development, production, exploration and acquisition of oil and gas properties, for fulfillment of working capital obligations, and for the repayment of revolving debt. As of March 31, 2007, the Company had a working capital deficit of $3.0 million, compared to a deficit of $7.4 million at December 31, 2006.

     During the three months ended March 31, 2007, cash used in operating activities was $4.3 million, compared to $3.7 million cash provided by operations in the prior year period. The increase in cash used in operating activities of $8.0 million was primarily due to cash used to decrease accounts payable and accrued liabilities outstanding at December 31, 2006 and the decrease in cash provided by income from discontinued operations.

     During the three months ended March 31, 2007, Infinity used $5.5 million in investing activities, compared to $13.0 million used in the prior year period. The decrease in cash used in investing activities of $7.5 million was primarily attributable to a $1.8 million decrease in oilfield services capital expenditures and a $5.7 million decrease in exploration and production capital expenditures, which reflects lower drilling activity in the Forth Worth Basin in 2007 as compared to 2006.

     During the three months ended March 31, 2007, cash provided by financing activities was $9.1 million, compared to $7.5 million provided by financing activities during the prior year period. The increase in cash provided by financing activities of $1.6 million was principally due to borrowings required to fund the decrease in net cash provided by operating activities caused somewhat by cash used to decrease accounts payable and accrued liabilities outstanding at December 31, 2006.

     On January 10, 2007, Infinity entered into a $50 million reserve-based revolving credit facility (the “Revolving Credit Facility”) with Amegy Bank N.A. (“Amegy”). Under the terms of the Revolving Credit Facility, Infinity may borrow, repay and re-borrow on a revolving basis up to the lesser of (i) the aggregate sums permitted under the borrowing base, initially set at $27 million, or (ii) $50 million. At closing, Infinity borrowed $8.9 million under the Revolving Credit Facility, which was used to settle past due trade payables, fund working capital needs and pay expenses of the financing transaction. Additional amounts borrowed under the facility may be used to fund the plan of development agreed to by Infinity and Amegy.

     The Revolving Credit Facility has an initial term of two years. Amounts borrowed bear interest at graduated variable rates based on LIBOR or the prime rate, which rates shall be adjusted based on the percentage of the applicable borrowing base used by Infinity from time to time. LIBOR rates can range between LIBOR plus 2.50% and LIBOR plus 3.25%, and prime rates can range between prime and prime plus 0.50%. Interest payments are due on a monthly basis and principal payments may be required under the Revolving Credit Facility 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 six months. Outstanding balances are secured by substantially all of the assets of Infinity and its subsidiaries.

     The Revolving Credit Facility contains certain standard continuing covenants and agreements and requires Infinity to maintain certain financial ratios and thresholds. The Company failed to meet certain of these financial covenants during the three months ended March 31, 2007. Amegy subsequently waived the violation of those covenants for the three months then ended.

     Under the Revolving Credit Facility, Infinity is subject to certain limitations with respect to hedging transactions. In addition, Infinity was required to enter into certain hedging transactions covering in the aggregate at least seventy percent (70%) of anticipated production from its proved developed producing oil and gas properties.

Outlook for 2007

     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 $17 million to $20 million during the remainder of 2007. Approximate capital expenditures by operating entity are anticipated to be $15 million to $18 million by Infinity-Texas; less than $1 million by Infinity-Wyoming; and less than $1 million by Infinity Energy Resources, Inc. The Company could also make capital expenditures for acquisitions or accelerated drilling activities in excess of these amounts should appropriate opportunities arise.

     The Company has a $50 million reserve-based Revolving Credit Facility with Amegy Bank N.A. (“Amegy”), under which Infinity may borrow, repay and re-borrow on a revolving basis up to the lesser of (i) the aggregate sums permitted under the borrowing base, initially set at $27 million, or (ii) $50 million. As of May 4, 2007, the Company had drawn $12.2 million under the Revolving Credit

Facility, and has $14.8 million available under the Revolving Credit Facility. The Revolving Credit Facility has an initial term of two years and amounts borrowed bear interest at graduated variable rates based on LIBOR or the prime rate, which rates shall be adjusted based on the percentage of the applicable borrowing base used by Infinity from time to time. LIBOR rates can range between LIBOR plus 2.50% and LIBOR plus 3.25%, and prime rates can range between prime and prime plus 0.50%.

     Depending on the market price for crude oil and natural gas during 2007, the number of wells ultimately drilled and stabilized production levels from wells expected to be placed on line during 2007, Infinity would expect to generate cash flow from operating activities during the remainder of 2007 of between $3 million and $6 million.

     In summary, Infinity believes that it will have approximately $19 million to $22 million available to it in 2007 from external financing, including borrowings under the Revolving Credit Facility, cash from operating activities, and cash collateral of $850,000 securing letters of credit related to its Nicaraguan concessions to fund its 2007 planned capital expenditures of $17 million to $20 million.

     Should Infinity identify acquisition opportunities, or if it wishes to accelerate the exploration and development of its oil and gas properties beyond that currently anticipated, or if cash flow from operating activities is not at levels anticipated, or if Infinity is unable to borrow under the Revolving Credit Facility, 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 Infinity’s planned capital expenditures are largely discretionary, Infinity could decrease the level of its planned capital expenditures.

Critical Accounting Policies and Estimates

     Infinity’s Annual Report on Form 10-K for the year ended December 31, 2006, 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 June 2006, the Financial Accounting Standards Board (“FASB”) issued FASB Interpretation Number 48 (“FIN 48”), Accounting for Uncertainty in Income Taxes – an Interpretation of FASB Statement No. 109. This interpretation clarifies the accounting for uncertainty in an enterprise’s financial statements in accordance with SFAS No. 109, Accounting for Income Taxes. This statement prescribes a recognition threshold and measurement of a tax position taken or expected to be taken in a tax return. This interpretation also provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure and transition. The adoption of FIN 48 by the Company on January 1, 2007, had no impact on its financial position or results of operations.

     In September 2006, the FASB issued SFAS No. 157, Fair Value Measurements. The standard provides guidance for using fair value to measure assets and liabilities. Under the standard, fair value refers to the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants in the market in which the reporting entity transacts. The

standard clarifies the principle that fair value should be based on the assumptions market participants would use when pricing the asset or liability. In support of this principle, the standard establishes a fair value hierarchy that prioritizes the information used to develop those assumptions. The statement is effective for financial statements issued for fiscal years beginning after November 15, 2007, and interim periods within those fiscal years. The Company is currently evaluating the statement to determine what impact, if any, it will have on the Company.

     In December 2006, the FASB issued FASB Staff Position (“FSP”) No. EITF 00-19-2, Accounting for Registration Payment Arrangements, which addresses an issuer’s accounting for registration payment arrangements. The FSP specifies that the contingent obligation to make future payments or otherwise transfer consideration under a registration payment arrangement, whether issued as a separate agreement or included as a provision of a financial instrument or other agreement, should be separately recognized and measured in accordance with FASB Statement No. 5, Accounting for Contingencies. The guidance in the FSP amends FASB Statements No. 133, Accounting for Derivative Instruments and Hedging Activities, and No. 150, Accounting for Certain Financial Instruments with Characteristics of both Liabilities and Equity, and FASB Interpretation No. 45, Guarantor’s Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness of Others, to include scope exceptions for registration payment arrangements. The FSP further clarifies that a financial instrument subject to a registration payment arrangement should be accounted for in accordance with other applicable generally accepted accounting principles without regard to the contingent obligation to transfer consideration pursuant to the registration payment arrangement. FSP No. EITF 00-19-2 was effective immediately for registration payment arrangements and the financial instruments subject to those arrangements that are entered into or modified subsequent to the date of issuance of the FSP. The adoption of FSP No. EITF 00-19-2 by the Company on January 1, 2007, had no material impact on its financial position or results of operations.

     During 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. The standard permits an entity to make an irrevocable election to measure most financial assets and financial liabilities at fair value. The fair value option may be elected on an instrument-by-instrument basis, with a few exceptions, as long as it is applied to the instrument in its entirety. Changes in fair value would be recorded in income. SFAS No. 159 established presentation and disclosure requirements intended to help financial statement users understand the effect of the entity’s election on earnings. SFAS No. 159 is effective as of the beginning of the first fiscal year beginning after November 15, 2007. Early adoption is permitted. The Company is currently evaluating the statement to determine what impact, if any, it will have on the Company.

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 $5.02 to a high of $7.15 per Mcf during the three months ended March 31, 2007. Oil price realizations ranged from a low of $40.33 per barrel to a high of $60.28 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. Through March 2006, the Company sold 2,000 MMBtu of natural gas per day under one fixed price physical contract. Sales under this fixed price contract were accounted for as normal sales agreements under the exemption in SFAS No. 133. For the three months ended March 31, 2006, the effect of Infinity’s sale of a portion of its gas production under a fixed price contract, compared to spot sales, was a decrease in revenue of approximately $0.3 million. The Company had no such fixed price contracts at March 31, 2007.

     As of March 31, 2007 the Company had the following oil swap and collar derivative arrangements outstanding:

						NYMEX				NYMEX				NYMEX
Term of Arrangements		Bbls per Day				Swap Price				Floor Price				Ceiling Price
April 1, 2007 — June 30, 2007			50							$	57.50			$	77.50
April 1, 2007 — September 30, 2007			50							$	60.00			$	85.50
July 1, 2007 — December 31, 2007			50							$	62.50			$	87.00
October 1, 2007 — March 31, 2008			50							$	62.00			$	85.60
April 1, 2008 — December 31, 2008			65			$	57.40
January 1, 2009 — December 31, 2009			55			$	57.95
January 1, 2010 — December 31, 2010			50			$	58.90

     As of March 31, 2007 the Company had the following natural gas swap and collar derivative arrangements outstanding:

		MMBtu				WAHA				WAHA				WAHA
Term of Arrangements		per Day				Swap Price				Floor Price				Ceiling Price
April 1, 2007 — June 30, 2007			1,000							$	6.00			$	10.55
July 1, 2007 — September 30, 2007			1,000							$	6.50			$	10.20
October 1, 2007 — December 31, 2007			1,000			$	6.915
January 1, 2008 — December 31, 2008			800			$	7.235
January 1, 2009 — December 31, 2009			600			$	7.170
January 1, 2010 — December 31, 2010			500			$	6.865

		MMBtu				CIG - RM
Term of Arrangement		per Day				Swap Price
April 1, 2007 — December 31, 2007			600			$	5.200
January 1, 2008 — December 31, 2008			400			$	6.475
January 1, 2009 — December 31, 2009			400			$	6.810
January 1, 2010 — December 31, 2010			300			$	6.565

Interest Rate Risk

     Infinity’s exposure to changes in interest rates results from our $10.0 million in floating rate debt at March 31, 2007. The result of a 10% fluctuation in the 3 month LIBOR 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 Principal Financial and Accounting 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 Principal Financial and Accounting Officer, has evaluated the effectiveness of the Company’s disclosure controls and procedures as of the end of the fiscal quarter covered by the Quarterly Report on Form 10-Q. The Company’s Chief Executive Officer and Principal Financial and Accounting 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 identified in connection with its evaluation occurred during the first quarter of 2007 that materially affected, or were reasonably likely to materially affect, the Company’s internal control over financial reporting.

PART II

ITEM 1. LEGAL PROCEEDINGS

     There are currently no pending material legal proceedings to which we are a party, that are not being defended by our general liability insurance carrier.

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, 2006.

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

     None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

     The Loan Agreement with Amegy Bank, N.A. contains certain standard continuing covenants and agreements and requires Infinity to maintain certain financial ratios and thresholds. The Company failed to meet certain of these financial covenants during the three months ended March 31, 2007, including the interest coverage ratio, debt service coverage ratio and funded debt to EBITDA ratio. Amegy subsequently waived the violation of those covenants for the three months then ended.

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

     There were no matters submitted to a vote of the Company’s stockholders during the first quarter of 2007.

ITEM 5. OTHER INFORMATION

     None.

ITEM 6. EXHIBITS

     (a) 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		May 9, 2007
Stanton E. Ross		(Principal Executive Officer)
/s/ James A. Tuell		President, Chief Operating Officer		May 9, 2007
James A. Tuell		(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)