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EXCEL - IDEA: XBRL DOCUMENT - Armada Oil, Inc.Financial_Report.xls
10-Q - FORM 10-Q - Armada Oil, Inc.v326171_10q.htm
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EX-31.1 - EXHIBIT 31.1 - Armada Oil, Inc.v326171_ex31-1.htm
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EX-4.4 - EXHIBIT 4.4 - Armada Oil, Inc.v326171_ex4-4.htm
v2.4.0.6
Summary of Significant Accounting Policies (Policy)
6 Months Ended
Sep. 30, 2012
Summary of Significant Accounting Policies [Abstract]  
Basis of Presentation

Basis of Presentation

 

The accompanying unaudited interim consolidated financial statements of Armada Oil, Inc. have been prepared in accordance with accounting principles generally accepted in the United States of America and the rules of the Securities and Exchange Commission and should be read in conjunction with the audited consolidated financial statements and notes thereto contained in the Company's latest Annual Report filed with the SEC on Form 10-K for the year ended March 31, 2012. In the opinion of management, all adjustments, consisting of normal recurring adjustments, necessary for a fair presentation of financial position and the results of operations for the interim periods presented have been reflected herein. The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year. Notes to the unaudited interim consolidated financial statements that would substantially duplicate the disclosures contained in the audited financial statements for the most recent fiscal year as reported in the Form 10-K have been omitted.

Principles of Consolidation

Principles of Consolidation

 

These consolidated financial statements presented are those of the Company and its wholly-owned subsidiaries, International Energy Corp., e.Deal Enterprises, Corp., and Armada Oil and Gas. Only Armada Oil and Gas is currently an active operating entity. All significant intercompany transactions and accounts have been eliminated in consolidation.

Estimates

Estimates

 

The preparation of financial statements in accordance with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates include accruals related to oil and gas sales and expenses; estimates used in determining oil and gas reserves, the carrying value of oil and gas properties, including the asset retirement obligations and related accretion, depletion, and impairment, if any, of such oil and gas properties; and assumptions used in the fair value of stock-based compensation.

Reclassifications

Reclassifications

 

Certain reclassifications have been made to prior fiscal period amounts or balances to conform to the presentation adopted in the current fiscal year.

Net Loss Per Share

Net Loss Per Share

 

The basic net loss per common share is computed by dividing the net loss by the weighted average number of common shares outstanding during a period. Diluted net loss per common share is computed by dividing the net loss, adjusted on an as if converted basis, by the weighted average number of common shares outstanding plus potential dilutive securities.

Cash and Cash Equivalents

Cash and Cash Equivalents

 

Cash and cash equivalents includes highly liquid investments with original maturities of three months or less. Currently the Company has amounts deposited with financial institutions in excess of federally insured limits.

Full Cost Method of Accounting for Oil and Gas Properties

Full Cost Method of Accounting for Oil and Gas Properties

 

The Company has elected to utilize the full cost method of accounting for its oil and gas activities. In accordance with the full cost method of accounting, all costs associated with the acquisition, exploration and development of oil and gas reserves, including directly related overhead costs, are capitalized.

 

All capitalized costs of oil and gas properties, including the estimated future costs to develop proved reserves, are amortized on the unit-of-production method using estimates of proved reserves once proved reserves are determined to exist. The Company has obtained a reserve study with estimated proven reserves, for its Young County, Texas Property. Accordingly, the Company recorded depletion expense of $41,058 related to this property during both the three and six month periods ended September 30, 2012. Accumulated depletion as of September 30, 2012 is $41,048.

 

Oil and gas properties without estimated proved reserves are not amortized until proved reserves associated with the properties can be determined or until impairment occurs. Based on a recent engineering report prepared with respect to the Wyoming Property, and review of the production data for the Archer County, Texas, Property, management has determined that no impairment currently exists with respect to those properties. Management is assessing geographic and production data to determine the need for reserve studies for these oil and gas properties.

Proved Reserves

Proved Reserves

 

Estimates of the Company's proved reserves included in this report are prepared in accordance with GAAP and guidelines from the United States Securities and Exchange Commission ("SEC"). The Company's engineering estimates of proved oil and natural gas reserves directly impact financial accounting estimates, including depreciation, depletion and amortization expense and impairment. Proved oil and natural gas reserves are the estimated quantities of oil and natural gas reserves that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under period-end economic and operating conditions. The process of estimating quantities of proved reserves is very complex, requiring significant subjective decisions in the evaluation of all geological, engineering and economic data for each reservoir. The accuracy of a reserve estimate is a function of: (i) the quality and quantity of available data; (ii) the interpretation of that data; (iii) the accuracy of various mandated economic assumptions, and (iv) the judgment of the persons preparing the estimate. The data for a given reservoir may change substantially over time as a result of numerous factors, including additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. Changes in oil and natural gas prices, operating costs and expected performance from a given reservoir also will result in revisions to the amount of the Company's estimated proved reserves. The Company engages independent reserve engineers to estimate its proved reserves.

Full Cost Ceiling Test

Full Cost Ceiling Test

 

At the end of each quarterly reporting period, the unamortized costs of oil and gas properties are subject to a "ceiling test" which basically limits capitalized costs to the sum of the estimated future net revenues from proved reserves, discounted at 10% per annum to present value, based on current economic and operating conditions, adjusted for related income tax effects. There was no ceiling test impairment during the three and six month periods ended September 30, 2012 or 2011.

Oil and Gas Revenue

Oil and Gas Revenue

 

The Company recognizes oil and gas revenue when oil and gas production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectability of the revenue is probable. Delivery occurs and title is transferred when production has been delivered to a purchaser's pipeline or truck. As a result of the numerous requirements necessary to gather information from purchasers or various measurement locations, calculate volumes produced, perform field and wellhead allocations, distribute and disburse funds to various working interest partners and royalty owners, the collection of revenues from oil and gas production may take up to 45 days following the month of production. Therefore, the Company may make accruals for revenues and accounts receivable based on estimates of its share of production. Since the settlement process may take 30 to 60 days following the month of actual production, the Company's financial results may include estimates of production and revenues for the related time period. The Company will record any differences between the actual amounts ultimately received and the original estimates in the period they become finalized.

Asset Retirement Obligation

Asset Retirement Obligation

 

The Company records the fair value of an asset retirement obligation ("ARO") in the period in which it is incurred if a reasonable estimate of fair value can be made. The present value of the estimated ARO is capitalized as part of the carrying amount of the long-lived asset and is depreciated over time as the discounted liability is accreted to its expected settlement value. The determination of fair value is based upon numerous estimates and assumptions, including future retirement costs, future recoverable quantities of oil and gas, future inflation rates and the credit-adjusted risk-free interest rate. The cost of the asset retirement obligation, less estimated salvage values, is included in the computation of depreciation, depletion, and amortization.

Stock-Based Compensation

Stock-Based Compensation

 

The Company measures all stock-based compensation awards using a fair value method on the date of grant and recognizes such expense in its consolidated financial statements over the requisite service period. The Company uses the Black-Scholes pricing model to determine the fair value of stock-based compensation awards. The Black-Scholes pricing model requires management to make assumptions regarding the warrant and option lives, expected volatility, and risk free interest rates. See "Note 8 Stock Options" and "Note 9 Warrants."

Income Taxes

Income Taxes

 

Deferred income tax assets and liabilities are determined based on the estimated future tax consequences attributable to net operating loss and credit carryforwards and temporary differences between the tax basis of assets and liabilities and their respective financial reporting amounts measured at the current enacted tax rates. The Company records an estimated valuation allowance on its deferred income tax assets if it is not more likely than not that these deferred income tax assets will be realized.

 

Income tax provisions or benefits for interim periods are computed based on the Company's estimated annual effective tax rate. Based on the Company's historical losses and its expectation of continuation of losses for the foreseeable future, the Company has determined that it is not more likely than not that deferred tax assets will be realized and, accordingly, has provided a full valuation allowance. As the Company anticipates or anticipated that its net deferred tax assets at March 31, 2013 and 2012 would be fully offset by a valuation allowance, there is no federal or state income tax benefit for the six months ended September 30, 2012 and 2011 related to the losses incurred during such periods.

Subsequent Events

Subsequent Events

 

The Company has evaluated all transactions from September 30, 2012 through the financial statement issuance date for subsequent events disclosure consideration.

Recently Issued and Adopted Accounting Pronouncements

New Accounting Pronouncements

 

The Company reviews new accounting standards as issued. Although some of these accounting standards issued or effective after the end of the Company's previous fiscal year may be applicable to the Company, it has not identified any standards that it believes merit further discussion. The Company believes that none of the new standards will have a significant impact on its consolidated financial position, operations or cash flows.