| Document And Entity Information | 9 Months Ended |
| Sep. 30, 2014 | |
| Document Information [Line Items] | ' |
| Entity Registrant Name | 'Woodgate Energy Corp |
| Entity Central Index Key | '0001558902 |
| Current Fiscal Year End Date | '--12-31 |
| Entity Filer Category | 'Smaller Reporting Company |
| Entity Common Stock, Shares Outstanding | 47,842,000 |
| Document Type | '10-Q |
| Amendment Flag | 'false |
| Document Period End Date | 30-Sep-14 |
| Document Fiscal Period Focus | 'Q3 |
| Document Fiscal Year Focus | '2014 |
| Consolidated Statements of Financial Position (USD $) | Sep. 30, 2014 | Dec. 31, 2013 |
| Current Assets | ' | ' |
| Cash and Cash Equivalents | $30,292 | $736,647 |
| Accounts Receivable - Related Party | 0 | 0 |
| Accrued Gas Sales | 16 | 506 |
| Prepaid Expense | 12,500 | 13,415 |
| Refundable Deposits | 11,204 | 11,204 |
| Total Current Asset | 54,012 | 761,772 |
| Fixed Assets | ' | ' |
| Property and Equipment | 34,265 | 34,265 |
| Furniture and Fixtures | 39,236 | 39,236 |
| Project Under Development | 19,996,389 | 19,009,407 |
| Less accumulated DD&A | -71,120 | -69,692 |
| Total Assets | 20,052,782 | 19,774,988 |
| LIABILITIES AND STOCKHOLDERS' EQUITY | ' | ' |
| Accounts Payable | 312,979 | 124,086 |
| Accounts Payable - Related Party | 143,618 | 142,749 |
| Accrued Expense | 889,154 | 906,045 |
| Payroll Tax Liabilities | 29,122 | 0 |
| Short Term Loans | 165,000 | 0 |
| Total Current Liabilities | 1,539,873 | 1,172,880 |
| Long-term Debt | ' | ' |
| Notes Payable - Related Parties | 453,981 | 453,981 |
| Total | 1,993,854 | 1,626,861 |
| Loss Incurring since inception | -6,472,526 | -5,886,327 |
| Stockholder's Equity (100,000,000 common shares authorized, 47,842,000 and 47,345,000 shares issued and outstanding as of September 30, 2014 and December 31, 2013 respectively) | 24,531,454 | 24,034,454 |
| Total Liabilities and Stockholders' Equity | $20,052,782 | $19,774,988 |
| Consolidated Statements of Financial Position (Parenthetical) | Sep. 30, 2014 | Dec. 31, 2013 |
| Common stock, shares authorized | 100,000,000 | 100,000,000 |
| Common stock, shares issued | 47,842,000 | 47,345,000 |
| Common stock, shares outstanding | 47,842,000 | 47,345,000 |
| Consolidated Statement of Operations (USD $) | 3 Months Ended | 9 Months Ended | 26 Months Ended | ||
| Sep. 30, 2014 | Sep. 30, 2013 | Sep. 30, 2014 | Sep. 30, 2013 | Sep. 30, 2014 | |
| Revenues | ' | ' | ' | ' | ' |
| Gas Sales | $0 | $827 | $437 | $2,968 | $24,330 |
| Total | 0 | 827 | 437 | 2,968 | 24,330 |
| Costs and Expenses | ' | ' | ' | ' | ' |
| Direct operating costs | 3,485 | -18,855 | 21,606 | 2,951 | 64,750 |
| General and administrative costs | ' | ' | ' | ' | ' |
| Adv. & Marketing Expenses | 18,000 | 820 | 33,800 | 820 | 38,463 |
| Bad Debt | 0 | 0 | 0 | 107,302 | 107,302 |
| Bank charges | 417 | 86 | 641 | 539 | 3,700 |
| Communication | 33 | 11 | 444 | 423 | 7,490 |
| Depreciation, depletion and amortization | 476 | -1,193 | 1,428 | -470 | 71,120 |
| Financing Cost | 4,213 | 0 | 12,545 | 0 | 671,083 |
| Insurance | 9,715 | 10,455 | 15,627 | 23,675 | 116,370 |
| Legal | 25,557 | 0 | 51,329 | 294 | 834,702 |
| License Fees | 0 | 252 | 814 | 378 | 19,830 |
| Miscellaneous | 96 | 81 | 459 | 1,319 | 45,486 |
| Payroll | 121,676 | 117,538 | 349,459 | 341,407 | 3,878,242 |
| Professional Fees | 32,356 | 96,129 | 51,537 | 454,303 | 3,442,553 |
| Rent | 11,910 | 11,862 | 35,667 | 36,791 | 269,262 |
| Regulatory | 0 | 0 | 650 | 0 | 651 |
| Supplies | 920 | 2,546 | 3,201 | 4,601 | 53,148 |
| Taxes | 0 | 0 | 0 | 4,028 | 6,820 |
| Travel | 0 | 22,225 | 8,558 | 33,600 | 466,868 |
| Utilities | 1,106 | 1,173 | 3,266 | 2,840 | 57,174 |
| Total | 229,960 | 243,130 | 591,031 | 1,014,801 | 10,155,014 |
| Operating Income | -229,960 | -242,303 | -590,594 | -1,011,833 | -10,130,684 |
| Interest, Expense and Other Income | ' | ' | ' | ' | ' |
| Other Income | 2,346 | 3,847 | 4,395 | 163,127 | 4,961,516 |
| Other Expense | 0 | 0 | 0 | 0 | -123,009 |
| Net unrealized gains (losses) on investments | 0 | 0 | 0 | -271,317 | -1,180,349 |
| Income from Continuing Operations | ($227,614) | ($238,456) | ($586,199) | ($1,120,023) | ($6,472,526) |
| Earnings (loss) per Common Share | ' | ' | ($0.01) | ($0.06) | ' |
| Consolidated Statement of Stockholders' Equity (USD $) | Total | Common Stock [Member] | Members' Capital [Member] | Additional Paid-in Capital [Member] | Retained Earnings [Member] |
| Balance at Dec. 31, 2011 | $8,126,802 | $0 | $11,141,469 | $0 | ($3,014,667) |
| Balance (in shares) at Dec. 31, 2011 | ' | 0 | ' | ' | ' |
| Issuance of Common Stock at inception of Woodgate Energy Corporation | 2,000 | 2,000 | 0 | 0 | 0 |
| Issuance of Common Stock at inception of Woodgate Energy Corporation (in shares) | ' | 20,000,000 | ' | ' | ' |
| Member Investment in E & P Co., LLC | 1,515,000 | 0 | 1,515,000 | 0 | 0 |
| Member Investment in Prestige O & G, LLC | 0 | 0 | 0 | 0 | 0 |
| Net Income/loss | -592,816 | 0 | 0 | 0 | -592,816 |
| Balance at Dec. 31, 2012 | 9,050,986 | 2,000 | 12,656,469 | 0 | -3,607,483 |
| Balance (in shares) at Dec. 31, 2012 | ' | 20,000,000 | ' | ' | ' |
| Issuance of Common Stock at inception of Woodgate Energy Corporation | 875 | 875 | 0 | 0 | 0 |
| Issuance of Common Stock at inception of Woodgate Energy Corporation (in shares) | ' | 8,750,000 | ' | ' | ' |
| Member Investment in E & P Co., LLC | 12,395,428 | ' | 12,395,428 | ' | ' |
| Member Investment in Prestige O & G, LLC | 454,441 | ' | 454,441 | ' | ' |
| Redemption of Common Stock | -1,950 | -1,950 | 0 | 0 | 0 |
| Redemption of Common Stock (in shares) | -19,500,000 | -19,500,000 | ' | ' | ' |
| Reverse Merger of E & P Co., LLC and Prestige O & G, LLC | -2,817,809 | 3,675 | -25,506,338 | 22,684,854 | 0 |
| Reverse Merger of E & P Co., LLC and Prestige O & G, LLC (in shares) | ' | 36,750,000 | ' | ' | ' |
| Shares issued by Private Placement | 1,345,000 | 135 | 0 | 1,344,865 | 0 |
| Shares issued by Private Placement (in shares) | ' | 1,345,000 | ' | ' | ' |
| Net Income/loss | -2,278,844 | 0 | 0 | 0 | -2,278,844 |
| Balance at Dec. 31, 2013 | 18,148,127 | 4,735 | 0 | 24,029,719 | -5,886,327 |
| Balance (in shares) at Dec. 31, 2013 | ' | 47,345,000 | ' | ' | ' |
| Shares issued by Private Placement | 497,000 | 50 | 0 | 496,950 | 0 |
| Shares issued by Private Placement (in shares) | ' | 497,000 | ' | ' | ' |
| Net Income/loss | -586,199 | 0 | 0 | 0 | -586,199 |
| Balance at Sep. 30, 2014 | $18,058,928 | $4,785 | $0 | $24,526,669 | ($6,472,526) |
| Balance (in shares) at Sep. 30, 2014 | ' | 47,842,000 | ' | ' | ' |
| Statement of Cash Flows (USD $) | 3 Months Ended | 9 Months Ended | 26 Months Ended | ||
| Sep. 30, 2014 | Sep. 30, 2013 | Sep. 30, 2014 | Sep. 30, 2013 | Sep. 30, 2014 | |
| Operating Activities | ' | ' | ' | ' | ' |
| Net Income | ($227,614) | ($238,456) | ($586,199) | ($1,120,023) | ($6,472,526) |
| Adjustments to reconcile Net Income to net Cash provided by Operations | ' | ' | ' | ' | ' |
| Accounts Payable | -148,372 | 74,817 | 189,762 | -280,408 | 4,475,320 |
| Accounts Receivable | 0 | -47,932 | 0 | 702,869 | 0 |
| Accrued Sale of Gas Income | -32 | -61 | -16 | 218 | -522 |
| Prepaid Expense | 0 | 0 | -915 | 1,309 | -14,330 |
| Credit Cards | 0 | 210 | 0 | 200 | 518 |
| Deposits | 0 | 0 | 0 | 0 | -11,204 |
| Depreciation | 476 | -1,193 | 1,428 | -470 | 71,120 |
| Direct Deposit Liabilities | 0 | 13,553 | 0 | 13,553 | 0 |
| Payroll Tax Liabilities | 22,615 | -5,246 | -29,122 | -3,457 | -29,298 |
| Accrued Expense | 3,213 | 6,036 | -16,890 | 233,272 | 946,210 |
| Net Cash Provided/(used) by Operating Activities | -349,714 | -198,272 | -441,952 | -452,937 | -1,034,712 |
| Investing Activities | ' | ' | ' | ' | ' |
| Notes Receivable | 0 | 0 | 0 | 0 | 0 |
| Projects Under Development | -66,084 | -95,863 | -986,982 | -613,743 | -19,996,388 |
| Property and Equipment | 0 | 0 | 0 | 0 | -73,501 |
| Investment in EPCO | 0 | 0 | 0 | 10,803,493 | 0 |
| Debt Support to EPCO | 0 | 0 | 0 | -289,119 | 0 |
| Net Cash Provided by (Used in) Investing Activities, Continuing Operations | -66,084 | -95,863 | -986,982 | 9,900,631 | -20,069,889 |
| Financing Activities | ' | ' | ' | ' | ' |
| Cash Balances from Subsidiaries | 3,638 | 53,100 | 60,579 | 53,100 | 60,579 |
| Notes Payables | 165,000 | -9,492,584 | 165,000 | -13,199,772 | 618,981 |
| Proceeds from Issuance of Stock | 230,000 | 1,295,017 | 497,000 | 1,293,066 | 499,157 |
| Proceeds from Stock Sale | 0 | 875 | 0 | 875 | 1,346,492 |
| Proceeds from Members/Stockholder's Contribution | 0 | 9,440,834 | 0 | 3,447,307 | 18,609,684 |
| Net Cash Provided by Financing Activities | 398,638 | 1,297,242 | 722,579 | -8,405,424 | 21,134,893 |
| Net Cash increase for period | -17,160 | 1,003,107 | -706,355 | 1,042,270 | 30,292 |
| Cash at Beginning of Period | 47,452 | 41,163 | 736,647 | 2,000 | 0 |
| Cash at end of Period | $30,292 | $1,044,270 | $30,292 | $1,044,270 | $30,292 |
| SUMMARY OF ACCOUNTING POLICIES | 9 Months Ended | ||
| Sep. 30, 2014 | |||
| Accounting Policies [Abstract] | ' | ||
| Significant Accounting Policies [Text Block] | ' | ||
| NOTE 1. | SUMMARY OF ACCOUNTING POLICIES | ||
| Principles of Consolidation. The Consolidated Financial Statements include the accounts of subsidiaries the Corporation controls. | |||
| Majority ownership is normally the indicator of control that is the basis on which subsidiaries are consolidated. However, certain factors may indicate that a majority-owned investment is not controlled and therefore should be accounted for using the equity method of accounting. These factors occur where the minority shareholders are granted by law or by contract substantive participating rights. These include the right to approve operating policies, expense budgets, financing and investment plans, and management compensation and succession plans. | |||
| Evidence of loss in value that might indicate impairment of investments in companies accounted for on the equity method is assessed to determine if such evidence represents a loss in value of the Corporation’s investment that is other than temporary. Examples of key indicators include a history of operating losses, a negative earnings and cash flow outlook, significant downward revisions to oil and gas reserves, and the financial condition and prospects for the investee’s business segment or geographic region. If evidence of an other than temporary loss in fair value below carrying amount is determined, an impairment is recognized. In the absence of market prices for the investment, discounted cash flows are used to assess fair value. | |||
| Revenue Recognition. The Corporation generally sells crude oil, natural gas and petroleum under short-term agreements at prevailing market prices. In some cases (e.g., natural gas), products may be sold under long-term agreements, with periodic price adjustments. Revenues are recognized when the products are delivered, which occurs when the customer has taken title and has assumed the risks and rewards of ownership, prices are fixed or determinable and collectibility is reasonably assured. | |||
| Derivative Instruments. The Corporation makes no use of derivative instruments. The Corporation does not engage in speculative derivative activities or derivative trading activities, nor does it use derivatives with leveraged features. | |||
| Fair Value. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market. | |||
| Property, Plant and Equipment. Depreciation, depletion and amortization, based on cost less estimated salvage value of the asset, are primarily determined under either the unit-of-production method or the straight-line method, which is based on estimated asset service life taking obsolescence into consideration. Maintenance and repairs, including planned major maintenance, are expensed as incurred. Major renewals and improvements are capitalized and the assets replaced are retired. | |||
| Interest costs incurred to finance expenditures during the construction phase of multiyear projects are capitalized as part of the historical cost of acquiring the constructed assets. The project construction phase commences with the development of the detailed engineering design and ends when the constructed assets are ready for their intended use. Capitalized interest costs are included in property, plant and equipment and are depreciated over the service life of the related assets. | |||
| The Corporation uses the “successful efforts” method to account for its exploration and production activities. Under this method, costs are accumulated on a field-by-field basis with certain exploratory expenditures and exploratory dry holes being expensed as incurred. Costs of productive wells and development dry holes are capitalized and amortized on the unit-of-production method. | |||
| The Corporation carries as an asset exploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and where the Corporation is making sufficient progress assessing the reserves and the economic and operating viability of the project. Exploratory well costs not meeting these criteria are charged to expense. Other exploratory expenditures, including geophysical costs and annual lease rentals, are expensed as incurred. | |||
| Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves. | |||
| Capitalized exploratory drilling and development costs associated with productive depletable extractive properties are amortized using unit-of-production rates based on the amount of proved developed reserves of oil, gas and other minerals that are estimated to be recoverable from existing facilities using current operating methods. | |||
| Under the unit-of-production method, oil and gas volumes are considered produced once they have been measured through meters at custody transfer or sales transaction points at the outlet valve on the lease or field storage tank. | |||
| Production involves lifting the oil and gas to the surface and gathering, treating, field processing and field storage of the oil and gas. The production function normally terminates at the outlet valve on the lease or field production storage tank. Production costs are those incurred to operate and maintain the Corporation’s wells and related equipment and facilities and are expensed as incurred. They become part of the cost of oil and gas produced. These costs, sometimes referred to as lifting costs, include such items as labor costs to operate the wells and related equipment; repair and maintenance costs on the wells and equipment; materials, supplies and energy costs required to operate the wells and related equipment; and administrative expenses related to the production activity. | |||
| Proved oil and gas properties held and used by the Corporation are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recoverable. Assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. | |||
| The Corporation estimates the future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. Cash flows used in impairment evaluations are developed using annually updated corporate plan investment evaluation assumptions for crude oil commodity prices, refining and chemical margins and foreign currency exchange rates. Annual volumes are based on field production profiles, which are also updated annually. Prices for natural gas and other products are based on corporate plan assumptions developed annually by major region and also for investment evaluation purposes. Cash flow estimates for impairment testing exclude derivative instruments. | |||
| Impairment analyses are generally based on proved reserves. Where probable reserves exist, an appropriately risk-adjusted amount of these reserves may be included in the impairment evaluation. An asset group would be impaired if the undiscounted cash flows were less than its carrying value. Impairments are measured by the amount the carrying value exceeds fair value. | |||
| Significant unproved properties are assessed for impairment individually, and valuation allowances against the capitalized costs are recorded based on the estimated economic chance of success and the length of time that the Corporation expects to hold the properties. Properties that are not individually significant are aggregated by groups and amortized based on development risk and average holding period. The valuation allowances are reviewed at least annually. | |||
| Gains on sales of proved and unproved properties are only recognized when there is neither uncertainty about the recovery of costs applicable to any interest retained nor any substantial obligation for future performance by the Corporation. | |||
| Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value. | |||
| Asset Retirement Obligations and Environmental Liabilities. The Corporation incurs retirement obligations for certain assets. The fair values of these obligations are recorded as liabilities on a discounted basis, which is typically at the time the assets are installed. The costs associated with these liabilities are capitalized as part of the related assets and depreciated. Over time, the liabilities are accreted for the change in their present value. | |||
| Liabilities for environmental costs are recorded when it is probable that obligations have been incurred and the amounts can be reasonably estimated. These liabilities are not reduced by possible recoveries from third parties and projected cash expenditures are not discounted. | |||
| Foreign Currency Translation. The Corporation selects the United States Dollar as the functional reporting currency for it’s based on the currency of the primary economic environment in which each subsidiary operates. | |||
| For all operations, gains or losses from remeasuring foreign currency transactions into the functional currency are included in income. | |||
| GOING CONCERN | 9 Months Ended | ||
| Sep. 30, 2014 | |||
| Going Concern Disclosure [Abstract] | ' | ||
| Going Concern Disclosure [Text Block] | ' | ||
| NOTE 2. | GOING CONCERN | ||
| The Company sustained operating losses since inception. It has losses at September 30, 2014 and December 31, 2013 of $586,199 and $2,278,844, respectively. The Company has an accumulated deficit of $6,472,526 since inception. The Company’s continuation as a going concern is dependent on its ability to generate sufficient cash flows from operations to meet its obligations, which it has not been able to accomplish to date, and/or obtain additional financing from its stockholders and/or other third parties. | |||
| These financial statements have been prepared on a going concern basis, which implies the Company will continue to meet its obligations and continue its operations for the next fiscal year. The continuation of the Company as a going concern is dependent upon financial support from stockholders and the ability of the Company to obtain necessary equity financing to continue operations. | |||
| There is no assurance that the Company will ever be profitable. The financial statements do not include any adjustments to reflect the possible future effect on the recoverability and classification of assets or the amounts and classifications of liabilities that may result should the Company be unable to continue as a growing concern. | |||
| Management has developed specific current and long-term plans to address its viability as a going concern as follows: | |||
| · | Upon registration, the Company will attempt to raise funds through equity offerings. If successful, these funds will be used to provide working capital. | ||
| · | In the longer term, the Company believes the cash flows from growth in its operations will provide resources for continued operations. | ||
| There can be no assurance the Company will have the ability to implement its business plan and to ultimately attain profitability. The Company’s long-term viability as a going concern is dependent upon three key factors: | |||
| · | The Company’s ability to obtain adequate sources of equity funding to meet current commitments and fund the continuation of its business operation in the near term. | ||
| · | The ability of the Company to control costs and expand revenues. | ||
| · | The ability of the Company to ultimately achieve adequate profitability and cash flows from operations to sustain its operations. | ||
| ACCOUNTING CHANGES | 9 Months Ended | ||
| Sep. 30, 2014 | |||
| Accounting Changes and Error Corrections [Abstract] | ' | ||
| Accounting Changes and Error Corrections [Text Block] | ' | ||
| NOTE 3. | ACCOUNTING CHANGES | ||
| The Corporation has not adopted authoritative guidance in 2014 having a material impact on the Corporation’s financial statements. | |||
| STOCKHOLDERS' EQUITY | 9 Months Ended | ||
| Sep. 30, 2014 | |||
| Stockholders' Equity Note [Abstract] | ' | ||
| Stockholders' Equity Note Disclosure [Text Block] | ' | ||
| NOTE 4. | STOCKHOLDERS’ EQUITY | ||
| The Company is authorized to issue 100,000,000 shares of common stock and 20,000,000 shares of preferred stock. | |||
| In July 2012, the Company issued 20,000,000 common shares to two directors and officers for an aggregated amount of $2,000 in cash. | |||
| On May 16, 2013, the Company redeemed an aggregate of 19,500,000 of the 20,000,000 outstanding shares at a redemption price of $.0001 per share for an aggregate redemption price of $1,950. | |||
| On May 17, 2013, the Company issued 8,750,000 shares of its common stock pursuant to Section 4(2) of the Securities Act of 1933 at par representing 94.5% of the total outstanding 9,250,000 shares of common stock. | |||
| In July 2013, the Company began to offer its common shares through private placement. The first sale was registered on July 30, 2013. By September 30, 2014, the Company had issued 1,842,000 shares of its common stock through private placement. | |||
| On September 6, 2013, the Company entered into a business combination with two LLCs – Prestige O & G, LLC and E & P Co., LLC, taking the form of a reverse merger. | |||
| The exchange closing took place on September 25, 2013 and the Company allotted a new issue of 36,750,000 to the members of Prestige O & G, LLC and E & P Co., LLC | |||
| As of September 30, 2014, the Company had 47,842,000 shares of common stock and no preferred stock issued and outstanding. | |||
| SUMMARY OF ACCOUNTING POLICIES (Policies) | 9 Months Ended |
| Sep. 30, 2014 | |
| Accounting Policies [Abstract] | ' |
| Consolidation, Policy [Policy Text Block] | ' |
| Principles of Consolidation. The Consolidated Financial Statements include the accounts of subsidiaries the Corporation controls. | |
| Majority ownership is normally the indicator of control that is the basis on which subsidiaries are consolidated. However, certain factors may indicate that a majority-owned investment is not controlled and therefore should be accounted for using the equity method of accounting. These factors occur where the minority shareholders are granted by law or by contract substantive participating rights. These include the right to approve operating policies, expense budgets, financing and investment plans, and management compensation and succession plans. | |
| Evidence of loss in value that might indicate impairment of investments in companies accounted for on the equity method is assessed to determine if such evidence represents a loss in value of the Corporation’s investment that is other than temporary. Examples of key indicators include a history of operating losses, a negative earnings and cash flow outlook, significant downward revisions to oil and gas reserves, and the financial condition and prospects for the investee’s business segment or geographic region. If evidence of an other than temporary loss in fair value below carrying amount is determined, an impairment is recognized. In the absence of market prices for the investment, discounted cash flows are used to assess fair value. | |
| Revenue Recognition, Policy [Policy Text Block] | ' |
| Revenue Recognition. The Corporation generally sells crude oil, natural gas and petroleum under short-term agreements at prevailing market prices. In some cases (e.g., natural gas), products may be sold under long-term agreements, with periodic price adjustments. Revenues are recognized when the products are delivered, which occurs when the customer has taken title and has assumed the risks and rewards of ownership, prices are fixed or determinable and collectibility is reasonably assured. | |
| Derivatives, Policy [Policy Text Block] | ' |
| Derivative Instruments. The Corporation makes no use of derivative instruments. The Corporation does not engage in speculative derivative activities or derivative trading activities, nor does it use derivatives with leveraged features. | |
| Fair Value Measurement, Policy [Policy Text Block] | ' |
| Fair Value. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market. | |
| Property, Plant and Equipment, Policy [Policy Text Block] | ' |
| Property, Plant and Equipment. Depreciation, depletion and amortization, based on cost less estimated salvage value of the asset, are primarily determined under either the unit-of-production method or the straight-line method, which is based on estimated asset service life taking obsolescence into consideration. Maintenance and repairs, including planned major maintenance, are expensed as incurred. Major renewals and improvements are capitalized and the assets replaced are retired. | |
| Interest costs incurred to finance expenditures during the construction phase of multiyear projects are capitalized as part of the historical cost of acquiring the constructed assets. The project construction phase commences with the development of the detailed engineering design and ends when the constructed assets are ready for their intended use. Capitalized interest costs are included in property, plant and equipment and are depreciated over the service life of the related assets. | |
| The Corporation uses the “successful efforts” method to account for its exploration and production activities. Under this method, costs are accumulated on a field-by-field basis with certain exploratory expenditures and exploratory dry holes being expensed as incurred. Costs of productive wells and development dry holes are capitalized and amortized on the unit-of-production method. | |
| The Corporation carries as an asset exploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and where the Corporation is making sufficient progress assessing the reserves and the economic and operating viability of the project. Exploratory well costs not meeting these criteria are charged to expense. Other exploratory expenditures, including geophysical costs and annual lease rentals, are expensed as incurred. | |
| Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves. | |
| Capitalized exploratory drilling and development costs associated with productive depletable extractive properties are amortized using unit-of-production rates based on the amount of proved developed reserves of oil, gas and other minerals that are estimated to be recoverable from existing facilities using current operating methods. | |
| Under the unit-of-production method, oil and gas volumes are considered produced once they have been measured through meters at custody transfer or sales transaction points at the outlet valve on the lease or field storage tank. | |
| Production involves lifting the oil and gas to the surface and gathering, treating, field processing and field storage of the oil and gas. The production function normally terminates at the outlet valve on the lease or field production storage tank. Production costs are those incurred to operate and maintain the Corporation’s wells and related equipment and facilities and are expensed as incurred. They become part of the cost of oil and gas produced. These costs, sometimes referred to as lifting costs, include such items as labor costs to operate the wells and related equipment; repair and maintenance costs on the wells and equipment; materials, supplies and energy costs required to operate the wells and related equipment; and administrative expenses related to the production activity. | |
| Proved oil and gas properties held and used by the Corporation are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recoverable. Assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. | |
| The Corporation estimates the future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. Cash flows used in impairment evaluations are developed using annually updated corporate plan investment evaluation assumptions for crude oil commodity prices, refining and chemical margins and foreign currency exchange rates. Annual volumes are based on field production profiles, which are also updated annually. Prices for natural gas and other products are based on corporate plan assumptions developed annually by major region and also for investment evaluation purposes. Cash flow estimates for impairment testing exclude derivative instruments. | |
| Impairment analyses are generally based on proved reserves. Where probable reserves exist, an appropriately risk-adjusted amount of these reserves may be included in the impairment evaluation. An asset group would be impaired if the undiscounted cash flows were less than its carrying value. Impairments are measured by the amount the carrying value exceeds fair value. | |
| Significant unproved properties are assessed for impairment individually, and valuation allowances against the capitalized costs are recorded based on the estimated economic chance of success and the length of time that the Corporation expects to hold the properties. Properties that are not individually significant are aggregated by groups and amortized based on development risk and average holding period. The valuation allowances are reviewed at least annually. | |
| Gains on sales of proved and unproved properties are only recognized when there is neither uncertainty about the recovery of costs applicable to any interest retained nor any substantial obligation for future performance by the Corporation. | |
| Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value. | |
| Asset Retirement Obligations and Environmental Cost, Policy [Policy Text Block] | ' |
| Asset Retirement Obligations and Environmental Liabilities. The Corporation incurs retirement obligations for certain assets. The fair values of these obligations are recorded as liabilities on a discounted basis, which is typically at the time the assets are installed. The costs associated with these liabilities are capitalized as part of the related assets and depreciated. Over time, the liabilities are accreted for the change in their present value. | |
| Liabilities for environmental costs are recorded when it is probable that obligations have been incurred and the amounts can be reasonably estimated. These liabilities are not reduced by possible recoveries from third parties and projected cash expenditures are not discounted. | |
| Foreign Currency Transactions and Translations Policy [Policy Text Block] | ' |
| Foreign Currency Translation. The Corporation selects the United States Dollar as the functional reporting currency for it’s based on the currency of the primary economic environment in which each subsidiary operates. | |
| For all operations, gains or losses from remeasuring foreign currency transactions into the functional currency are included in income. | |
| GOING CONCERN (Details Textual) (USD $) | 3 Months Ended | 9 Months Ended | 12 Months Ended | 26 Months Ended | |||
| Sep. 30, 2014 | Sep. 30, 2013 | Sep. 30, 2014 | Sep. 30, 2013 | Dec. 31, 2013 | Dec. 31, 2012 | Sep. 30, 2014 | |
| Going Concern Disclosure [Line Items] | ' | ' | ' | ' | ' | ' | ' |
| Net Income (Loss) Attributable to Parent | ($227,614) | ($238,456) | ($586,199) | ($1,120,023) | ($2,278,844) | ($592,816) | ($6,472,526) |
| Development Stage Enterprise, Deficit Accumulated During Development Stage | $6,472,526 | ' | $6,472,526 | ' | $5,886,327 | ' | $6,472,526 |
| STOCKHOLDERS' EQUITY (Details Textual) (USD $) | 1 Months Ended | 12 Months Ended | 1 Months Ended | 9 Months Ended | 12 Months Ended | 12 Months Ended | 9 Months Ended | 12 Months Ended | |||||
| 31-May-13 | Dec. 31, 2013 | Dec. 31, 2012 | Sep. 30, 2014 | 16-May-13 | 31-May-13 | Sep. 30, 2014 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | Dec. 31, 2012 | Sep. 30, 2014 | Dec. 31, 2013 | |
| Common Stock [Member] | Common Stock [Member] | Common Stock [Member] | Common Stock [Member] | Common Stock [Member] | Common Stock [Member] | Common Stock [Member] | Subsidiaries [Member] | ||||||
| Director And Officer [Member] | Private Placement [Member] | ||||||||||||
| Stockholder's Equity [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
| Common Stock, Shares Authorized | ' | 100,000,000 | ' | 100,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
| Preferred Stock, Shares Authorized | ' | ' | ' | 20,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
| Development Stage Entities, Stock Issued, Shares, Issued for Cash | ' | ' | ' | ' | ' | 8,750,000 | ' | 8,750,000 | 20,000,000 | ' | 20,000,000 | ' | ' |
| Stock Redeemed or Called During Period, Shares | ' | 19,500,000 | ' | ' | ' | ' | ' | 19,500,000 | ' | ' | ' | ' | ' |
| Shares, Outstanding | ' | ' | ' | ' | 20,000,000 | ' | 47,842,000 | 47,345,000 | 20,000,000 | 0 | ' | ' | ' |
| Share Price | ' | ' | ' | ' | $0.00 | ' | ' | ' | ' | ' | ' | ' | ' |
| Percentage of Common Stock Outstanding | 94.50% | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
| Development Stage Entities, Stock Issued, Value, Issued for Cash | ' | $875 | $2,000 | ' | ' | $9,250,000 | ' | $875 | $2,000 | ' | $2,000 | ' | ' |
| Stock Issued During Period, Shares, New Issues | ' | ' | ' | ' | ' | ' | 497,000 | 1,345,000 | ' | ' | ' | 1,842,000 | 36,750,000 |
| Preferred Stock, Shares Issued | ' | ' | ' | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
| Preferred Stock, Shares Outstanding | ' | ' | ' | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
| Redemption of Common Stock | $1,950 | ($1,950) | ' | ' | ' | ' | ' | ($1,950) | ' | ' | ' | ' | ' |
