Summary Of Significant Accounting Policies	12 Months Ended
Dec. 31, 2014
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	NOTE 3 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Cash and Cash Equivalents The Company considers all highly liquid investments with the original maturities of three months or less to be cash equivalents. The Company had $5 and $2,035 of cash and cash equivalents at December 31, 2014 and 2013, respectively. Use of Estimates The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates made in preparing these financial statements include the estimate of proved oil and gas reserves and related present value estimates of future net cash flows therefrom and the assessment of asset retirement obligations. Recent Accounting Pronouncements The Company has evaluated recent accounting pronouncements and their adoption has not had or is not expected to have a material impact on the Company’s financial position or statements. Reclassification of Financial Statement Accounts Certain amounts in the December 31, 2013 financial statements have been reclassified to conform to the presentation in the December 31, 2014 financial statements. Oil and Gas Properties The Company uses the full cost method of accounting for oil and natural gas properties. Under this method, all acquisition, exploration and development costs, including certain payroll, asset retirement costs, other internal costs, and interest incurred for the purpose of finding oil and natural gas reserves, are capitalized. Internal costs that are capitalized are directly attributable to acquisition, exploration and development activities and do not include costs related to production, general corporate overhead or similar activities. Costs associated with production and general corporate activities are expensed in the period incurred. Proceeds from the sale of oil and natural gas properties are applied to reduce the capitalized costs of oil and natural gas properties unless the sale would significantly alter the relationship between capitalized costs and proved reserves, in which case a gain or loss is recognized. Capitalized costs associated with impaired properties and capitalized costs related to properties having proved reserves, plus the estimated future development costs, and asset retirement costs under Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 410 “Asset Retirement and Environmental Obligations” (FASB ASC 410), are amortized using the unit-of-production method based on proved reserves. Capitalized costs of oil and natural gas properties, net of accumulated amortization and deferred income taxes, are limited to the total of estimated future net cash flows from proved oil and natural gas reserves, discounted at ten percent, plus the cost of unevaluated properties. There are many factors, including global events that may influence the production, processing, marketing and price of oil and natural gas. A reduction in the valuation of oil and natural gas properties resulting from declining prices or production could adversely impact depletion rates and capitalized cost limitations. Capitalized costs associated with properties that have not been evaluated through drilling or seismic analysis, including exploration wells in progress, are excluded from the unit-of-production amortization. Exclusions are adjusted annually based on drilling results and interpretative analysis. Sales of oil and natural gas properties are accounted for as adjustments to the net full cost pool with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. If it is determined that the relationship is significantly altered, the corresponding gain or loss will be recognized in the statements of operations. Costs of oil and gas properties are depleted using the unit-of-production method. For the years ended December 31, 2014 and 2013, the Company recognized $181,008 and $263,987, respectively of depletion expense related to oil and gas production. Ceiling Test – In applying the full cost method and in accordance with ASC 932, the Company performs an impairment test (ceiling test) at each reporting date, whereby the carrying value of property and equipment is compared to the value of its proved reserves discounted at a ten percent interest rate of future net revenues, based on current economic and operating conditions, plus the cost of properties not being amortized, plus the lower of cost or fair market value of unproved properties included in costs being amortized, less the income tax effects related to book and tax basis differences of the properties. During the years ended December 31, 2014 and 2013, no impairment expense was recorded in connection with the full cost ceiling test calculation. Revenue Recognition – Revenues from the sale of oil and natural gas are recognized when the product is delivered at a fixed or determinable price, title has transferred, and collectability is reasonably assured. For oil sales, this occurs when the customer takes delivery of oil from the operators’ storage tanks. Asset Retirement Obligations The Company records the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. The liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized. Long-Lived Assets Long-lived assets include equipment and intangible assets other than those with indefinite lives. We assess the carrying value of our long-lived asset groups when indicators of impairment exist and recognize an impairment loss when the carrying amount of a long-lived asset is not recoverable from the undiscounted cash flows expected to result from the use and eventual disposition of the asset. Indicators of impairment include significant underperformance relative to historical or projected future operating results, significant changes in our use of the assets or in our business strategy, loss of or changes in customer relationships and significant negative industry or economic trends. When indications of impairment arise for a particular asset or group of assets, we assess the future recoverability of the carrying value of the asset (or asset group) based on an undiscounted cash flow analysis. If carrying value exceeds projected, net, undiscounted cash flows, an additional analysis is performed to determine the fair value of the asset (or asset group), typically a discounted cash flow analysis, and an impairment charge is recorded for the excess of carrying value over fair value. Property and equipment are recorded at historical cost less accumulated depreciation, unless impaired. Depreciation is charged to operations over the estimated useful lives of the assets using the straight-line. Upon retirement or sale, the historical cost of assets disposed of and the related accumulated depreciation are removed from the accounts and any resulting gain or loss is recognized. Expenditures for repairs and maintenance are charged to expense as incurred. Income Taxes Income taxes are provided in accordance with FASB Codification Topic 740, Accounting for Income Taxes. A deferred tax asset or liability is recorded for all temporary differences between financial and tax reporting and net operating loss-carry forwards. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax asset will not be realized. Deferred tax assets and liabilities are adjusted for the effect of changes in tax laws and rates on the date of enactment. The asset and liability approach is used to account for income taxes by recognizing deferred tax assets and liabilities for the expected future tax consequences of temporary differences between the carrying amounts and the tax basis of assets and liabilities. The Company records a valuation allowance to reduce the deferred tax assets to the amount that is more likely than not to be realized. Fair Value Measurements The fair value of a financial instrument is the amount that could be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Financial assets are marked to bid prices and financial liabilities are marked to offer prices. Fair value measurements do not include transaction costs. A fair value hierarchy is used to prioritize the quality and reliability of the information used to determine fair values. Categorization within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement. The fair value hierarchy is defined into the following three categories: Level 1: Quoted market prices in active markets for identical assets or liabilities Level 2: Observable market-based inputs or inputs that are corroborated by market data Level 3: Unobservable inputs that are not corroborated by market data Basic and Diluted Loss per Share Basic and diluted loss per share is calculated by dividing the Company’s net loss applicable to common shareholders by the weighted average number of common shares during the period. Diluted earnings per share is calculated by dividing the Company’s net income available to common shareholders by the diluted weighted average number of shares outstanding during the year. The diluted weighted average number of shares outstanding is the basic weighted number of shares adjusted for any potentially dilutive debt or equity. There were -0- and 202,020 such common stock equivalents outstanding as of December 31, 2014 and 2013, respectively.

Summary Of Significant Accounting Policies

12 Months Ended

Dec. 31, 2014

Summary of Significant Accounting Policies

NOTE 3 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Cash and Cash Equivalents

The Company considers all highly liquid investments with the original maturities of three months or less to be cash equivalents. The Company had $5 and $2,035 of cash and cash equivalents at December 31, 2014 and 2013, respectively.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates made in preparing these financial statements include the estimate of proved oil and gas reserves and related present value estimates of future net cash flows therefrom and the assessment of asset retirement obligations.

Recent Accounting Pronouncements

The Company has evaluated recent accounting pronouncements and their adoption has not had or is not expected to have a material impact on the Company’s financial position or statements.

Reclassification of Financial Statement Accounts

Certain amounts in the December 31, 2013 financial statements have been reclassified to conform to the presentation in the December 31, 2014 financial statements.

Oil and Gas Properties

The Company uses the full cost method of accounting for oil and natural gas properties. Under this method, all acquisition, exploration and development costs, including certain payroll, asset retirement costs, other internal costs, and interest incurred for the purpose of finding oil and natural gas reserves, are capitalized. Internal costs that are capitalized are directly attributable to acquisition, exploration and development activities and do not include costs related to production, general corporate overhead or similar activities. Costs associated with production and general corporate activities are expensed in the period incurred. Proceeds from the sale of oil and natural gas properties are applied to reduce the capitalized costs of oil and natural gas properties unless the sale would significantly alter the relationship between capitalized costs and proved reserves, in which case a gain or loss is recognized.

Capitalized costs associated with impaired properties and capitalized costs related to properties having proved reserves, plus the estimated future development costs, and asset retirement costs under Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 410 “Asset Retirement and Environmental Obligations” (FASB ASC 410), are amortized using the unit-of-production method based on proved reserves. Capitalized costs of oil and natural gas properties, net of accumulated amortization and deferred income taxes, are limited to the total of estimated future net cash flows from proved oil and natural gas reserves, discounted at ten percent, plus the cost of unevaluated properties.

There are many factors, including global events that may influence the production, processing, marketing and price of oil and natural gas. A reduction in the valuation of oil and natural gas properties resulting from declining prices or production could adversely impact depletion rates and capitalized cost limitations. Capitalized costs associated with properties that have not been evaluated through drilling or seismic analysis, including exploration wells in progress, are excluded from the unit-of-production amortization. Exclusions are adjusted annually based on drilling results and interpretative analysis.

Sales of oil and natural gas properties are accounted for as adjustments to the net full cost pool with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. If it is determined that the relationship is significantly altered, the corresponding gain or loss will be recognized in the statements of operations.

Costs of oil and gas properties are depleted using the unit-of-production method. For the years ended December 31, 2014 and 2013, the Company recognized $181,008 and $263,987, respectively of depletion expense related to oil and gas production.

Ceiling Test – In applying the full cost method and in accordance with ASC 932, the Company performs an impairment test (ceiling test) at each reporting date, whereby the carrying value of property and equipment is compared to the value of its proved reserves discounted at a ten percent interest rate of future net revenues, based on current economic and operating conditions, plus the cost of properties not being amortized, plus the lower of cost or fair market value of unproved properties included in costs being amortized, less the income tax effects related to book and tax basis differences of the properties. During the years ended December 31, 2014 and 2013, no impairment expense was recorded in connection with the full cost ceiling test calculation.

Revenue Recognition – Revenues from the sale of oil and natural gas are recognized when the product is delivered at a fixed or determinable price, title has transferred, and collectability is reasonably assured. For oil sales, this occurs when the customer takes delivery of oil from the operators’ storage tanks.

Asset Retirement Obligations

The Company records the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. The liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized.

Long-Lived Assets

Long-lived assets include equipment and intangible assets other than those with indefinite lives. We assess the carrying value of our long-lived asset groups when indicators of impairment exist and recognize an impairment loss when the carrying amount of a long-lived asset is not recoverable from the undiscounted cash flows expected to result from the use and eventual disposition of the asset. Indicators of impairment include significant underperformance relative to historical or projected future operating results, significant changes in our use of the assets or in our business strategy, loss of or changes in customer relationships and significant negative industry or economic trends. When indications of impairment arise for a particular asset or group of assets, we assess the future recoverability of the carrying value of the asset (or asset group) based on an undiscounted cash flow analysis. If carrying value exceeds projected, net, undiscounted cash flows, an additional analysis is performed to determine the fair value of the asset (or asset group), typically a discounted cash flow analysis, and an impairment charge is recorded for the excess of carrying value over fair value.

Property and equipment are recorded at historical cost less accumulated depreciation, unless impaired. Depreciation is charged to operations over the estimated useful lives of the assets using the straight-line. Upon retirement or sale, the historical cost of assets disposed of and the related accumulated depreciation are removed from the accounts and any resulting gain or loss is recognized. Expenditures for repairs and maintenance are charged to expense as incurred.

Income Taxes

Income taxes are provided in accordance with FASB Codification Topic 740, Accounting for Income Taxes. A deferred tax asset or liability is recorded for all temporary differences between financial and tax reporting and net operating loss-carry forwards.

Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax asset will not be realized. Deferred tax assets and liabilities are adjusted for the effect of changes in tax laws and rates on the date of enactment.

The asset and liability approach is used to account for income taxes by recognizing deferred tax assets and liabilities for the expected future tax consequences of temporary differences between the carrying amounts and the tax basis of assets and liabilities. The Company records a valuation allowance to reduce the deferred tax assets to the amount that is more likely than not to be realized.

Fair Value Measurements

The fair value of a financial instrument is the amount that could be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Financial assets are marked to bid prices and financial liabilities are marked to offer prices. Fair value measurements do not include transaction costs. A fair value hierarchy is used to prioritize the quality and reliability of the information used to determine fair values. Categorization within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement. The fair value hierarchy is defined into the following three categories:

Level 1: Quoted market prices in active markets for identical assets or liabilities

Level 2: Observable market-based inputs or inputs that are corroborated by market data

Level 3: Unobservable inputs that are not corroborated by market data

Basic and Diluted Loss per Share

Basic and diluted loss per share is calculated by dividing the Company’s net loss applicable to common shareholders by the weighted average number of common shares during the period. Diluted earnings per share is calculated by dividing the Company’s net income available to common shareholders by the diluted weighted average number of shares outstanding during the year. The diluted weighted average number of shares outstanding is the basic weighted number of shares adjusted for any potentially dilutive debt or equity. There were -0- and 202,020 such common stock equivalents outstanding as of December 31, 2014 and 2013, respectively.

- Definition

The entire disclosure for all significant accounting policies of the reporting entity.

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