Woodgate Energy 10-K/A 29 Aug 14 2013 FY Annual report (amended) Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Jul. 11, 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	'	47,612,000
Document Type	'10-K	'
Amendment Flag	'true	'
Amendment Description	'Restated Auditor Opinion for 2013 post revision of the financial statements presented in Form 10-k Amendment no. 1. Also, changes in Financial footnotes to explain the impact of removal of intangible assets from Woodgate financials.	'
Document Period End Date	31-Dec-13	'
Document Fiscal Period Focus	'FY	'
Document Fiscal Year Focus	'2013	'
Entity Well-known Seasoned Issuer	'No	'
Entity Voluntary Filers	'No	'
Entity Current Reporting Status	'Yes	'
Entity Public Float	'	$0

Consolidated_Statements_of_Fin

Consolidated Statements of Financial Position (USD $)	Dec. 31, 2013	Dec. 31, 2012
Current Assets	'	'
Cash and Cash Equivalents	$736,647	$55,100
Accounts Receivable - Related Party	0	562,438
Accrued Gas Sales	506	0
Prepaid Expense	13,415	13,809
Refundable Deposits	11,204	11,204
Total Current Asset	761,772	642,551
Fixed Assets	'	'
Property and Equipment	34,265	33,403
Furniture and Fixtures	39,236	39,236
Project Under Development	19,009,407	18,351,693
Intangibles	0	0
Less accumulated DD&A	-69,692	-69,746
Total Assets	19,774,988	18,997,137
LIABILITIES AND STOCKHOLDERS' EQUITY	'	'
Accounts Payable	124,086	640,075
Accounts Payable - Related Party	142,749	58,685
Accrued Expense	906,045	132,463
Payroll Tax Liabilities	0	0
Direct Deposit Liabilities	0	0
Notes Payable	0	714,928
Total Current Liabilities	1,172,880	1,546,151
Long-term Debt	'	'
Notes Payable - Related Parties	453,981	8,400,000
Total	1,626,861	9,946,151
Loss Incurring Since Inception	-5,886,327	-3,765,749
Stockholder's Equity (100,000,000 common shares authorized, 47,345,000 and 20,000,000 shares issued and outstanding) as of December 31, 2013 and December 31, 2012 respectively	24,034,454	12,816,735
Total Liabilities and Stockholders' Equity	$19,774,988	$18,997,137

Consolidated_Statements_of_Fin1

Consolidated Statements of Financial Position (Parenthetical)	Dec. 31, 2013	Dec. 31, 2012
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares issued	47,345,000	20,000,000
Common stock, shares outstanding	47,345,000	20,000,000

Consolidated_Statement_of_Oper

Consolidated Statement of Operations (USD $)	12 Months Ended		103 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
Revenues	'	'	'
Gas Sales	$3,845	$4,420	$23,893
Total	3,845	4,420	23,893
Costs and Expenses	'	'	'
Direct operating costs	3,083	2,433	39,659
General and administrative costs	'	'	0
Adv. & Marketing Expenses	820	0	4,663
Bad Debt	107,302	0	107,302
Bank charges	638	345	3,059
Communication	651	6,395	7,046
Depreciation, depletion and amortization	-55	2,893	69,692
Employee insurance	0	0	0
Financing Cost	357,519	0	658,537
Insurance	17,685	29,436	98,028
Legal	144,129	133,416	783,373
License Fees	378	124	19,016
Miscellaneous	2,439	2,794	45,028
Payroll	972,319	590,587	3,531,498
Professional Fees	420,754	21,381	3,391,016
Rent	48,653	44,043	233,596
Supplies	7,168	5,384	49,948
Taxes	4,365	332	6,820
Travel	86,593	47,880	458,310
Utilities	4,103	962	53,908
Total	2,178,544	888,405	9,560,499
Operating Income	-2,174,699	-883,985	-9,536,606
Interest, Expense and Other Income	'	'	'
Other Income	167,210	558,793	4,957,120
Other Expense	-38	0	-126,492
Net unrealized gains (losses) on investments	-271,317	-267,624	-1,180,349
Income from Continuing Operations	($2,278,844)	($592,816)	($5,886,327)
Earnings (loss) per Common Share	($0.06)	($0.02)	'

Consolidated_Statement_of_Cash

Consolidated Statement of Cash Flows (USD $)	12 Months Ended		103 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
Operating Activities	'	'	'
Net Income	($2,278,844)	($592,816)	($5,886,327)
Adjustments to reconcile Net Income to net Cash provided by Operations	'	'	'
Accounts Payable	-521,504	594,550	4,285,558
Accounts Receivable	660,320	-437,561	0
Accrued Expense	770,638	-288,244	963,100
Accrued Interest	0	139,077	0
Accrued Sale of Gas Income	427	-690	-506
Credit Cards	509	-17	518
Deposits	0	-3,928	-11,204
Depreciation	-55	2,893	69,692
Investments	0	1,542,510	0
Note Receivable - Related Party	'	-412,500	0
Payroll Tax Liabilities	-8,449	8,305	-176
Prepaid Expense	394	12,043	-13,415
Net Cash Provided/(used) by Operating Activities	-1,376,564	563,622	-592,760
Investing Activities	'	'	'
Investment in EPCO	5,474,074	267,624	0
Notes Receivable - Related Party	4,537,500	0	0
Projects Under Development	-340,448	-965,360	-19,009,406
Property & Equipment	-861	-388	-73,501
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	9,670,265	-698,124	-19,082,907
Financing Activities	'	'	'
Notes Payables	-13,198,447	-1,239,922	453,981
Proceeds from Issuance of Stock	0	2,000	2,157
Proceeds from Stock Sale	1,347,292	0	1,346,492
Proceeds from Members/Stockholder's Contribution	4,239,001	1,516,007	18,609,684
Net Cash Provided by Financing Activities	-7,612,154	278,085	20,412,314
Net Cash increase for period	681,547	143,583	736,647
Cash at Beginning of Period	55,100	-88,483	0
Cash at end of Period	$736,647	$55,100	$736,647

Consolidated_Statement_of_Stoc

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	'	'	'
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	'	'	'

SUMMARY_OF_ACCOUNTING_POLICIES

SUMMARY OF ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2013
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

GOING CONCERN	12 Months Ended
	Dec. 31, 2013
Going Concern Disclosure [Abstract]	'
Going Concern Disclosure [Text Block]	'
		NOTE 2.	GOING CONCERN
	The Company sustained operating losses since inception. It has losses at December 31, 3013 and 2012 of $2,278,844 and $592,816, respectively. The Company has an accumulated deficit of $5,886, 237 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

ACCOUNTING CHANGES	12 Months Ended
	Dec. 31, 2013
Accounting Changes and Error Corrections [Abstract]	'
Accounting Changes and Error Corrections [Text Block]	'
		NOTE 3.	ACCOUNTING CHANGES
	The Corporation did not adopt authoritative guidance in 2013 that had a material impact on the Corporation’s financial statements.
	The Company had originally valued its estimation of the Company’s trade secrets, holding these secrets to be intangible assets that had previously not been accounted for. After substantial discussion with legal counsel and the Securities and Exchange Commission, among others, it was agreed that the evaluation could not be properly substantiated without extended litigation. As such, management made the decision to abandon its trade secret theory, reducing both the equity it believed held and the value it believed held in those intangible assets.

STOCKHOLDERS_EQUITY

STOCKHOLDERS' EQUITY	12 Months Ended
	Dec. 31, 2013
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 December 31, 2013, the Company had issued 1,345,000 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 December 31, 2013, 47,345,000 shares of common stock and no preferred stock were issued and outstanding.

MANAGEMENTS_DISCUSSION_AND_ANA

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Quarterly Financial Information [Text Block]	'
		NOTE 5.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
	Cash and Cash Equivalents
	At December 31, 2013 and 2012, the Company had Cash and Cash Equivalents consisting of $736,647 and $55,100, respectively.
	Accounts Receivable
	At December 31, 2013 and 2012, the Company had Accounts Receivable – Related Party consisting of $ 0 and $562,438, respectively.
	Projects Under Developments
	At December 31, 2013 and 2012, the Company’s Projects Under Development were $19,009,407 and $18,351,693, respectively.
	Entity		2013		2012
	Woodgate Energy Corporation (Parent)			-		-
	E & P Co., LLC (Subsidiary)			8,869,848		18,001,693
	Prestige O & G, LLC (Subsidiary)			10,139,559		350,000
	Total			19,009,407		18,351,693
	Notes Payable
	At December 31, 2013 and 2012, the Company held Notes Payable consisting of $453,981 and $9,114,928, respectively.
	Entity		2013		2012
	Woodgate Energy Corporation (Parent)			-		-
	E & P Co., LLC (Subsidiary)			453,981		9,114,928
	Prestige O & G, LLC (Subsidiary)			-		-
	Total			453,981		9,114,928
	Accounts Payable
	At December 31, 2013 and 2012, the Company held Accounts Payable consisting of $266,835 and $698,760, respectively.
	Entity		2013		2012
	Woodgate Energy Corporation (Parent)			-		-
	E & P Co., LLC (Subsidiary)			266,835		698,760
	Prestige O & G, LLC (Subsidiary)			-		-
	Total			266,835		698,760
	Revenues
	As of December 31, 2013 and 2012, Woodgate had limited revenues of gas sales in the amount of $3,845 and $4,420 and had limited income or cash flows from operations. The continuation of Woodgate as a going concern is dependent upon financial support from its stockholders or its ability to obtain necessary equity financing to continue operations.
	Earnings Per Share
	For the years ending December 31, 2013 and 2012, the company recorded losses of $2,278,844 and $592,816, respectively. This resulted in Earnings Per Share of ($0.06) and ($0.02) for those respective year ends. The majority of these losses are attributable to operational expenses incurred by the subsidiaries of the Company.
	Litigation and other Contingencies
	Management has regular litigation reviews, including updates from corporate and outside counsel, to assess the need for accounting recognition or disclosure of these contingencies. The Company accrues an undiscounted liability for those contingencies where the incurrence of loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. The Company does not record liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or when the liability is believed to be only reasonably possible or remote. For purposes of our contingency disclosures, “significant” includes material matters as well as other matters which management believes should be disclosed. Woodgate Energy Corporation will continue to defend itself vigorously in these matters. Based on a consideration of all relevant facts and circumstances, the Company does not believe the ultimate outcome of any currently pending lawsuit against Woodgate Energy Corporation will have a material adverse effect upon the Company’s operations, financial condition, or financial statements taken as a whole.
	On April 16, 2009, Noram Drilling Company filed an original complaint against E & P Co. International, LLC and E & P Co., LLC in the 37th District Court of Louisiana, arguing E & P Co., LLC was liable for breach of contract by E & P Co., LLC under the theory of single enterprise liability. The Company argues no such single enterprise liability exists as the contract is to be construed under Texas law. On January 16, 2013, the 37th District Court in the Parish of Caldwell, Louisiana, the court granted E & P Co., LLC’s Motion for Summary Judgment, holding the Company not to be a party to the drilling contract. The Court further denied NorAm’s Motion for Summary Judgment for damages. On December 11, 2013, the Court of Appeals of the Second Circuit of the State of Louisiana affirmed the trial court’s finding.
	At this time, the company is subject to no legal proceedings and the Company is unaware of any proceedings contemplated against it.
	Supplemental Information on Oil and Gas Exploration and Production
	The results of operations for producing activities shown below do not include earnings from nonoperating activities.
	Results of Operations for the Years Ending		2013		2012
	Revenue
	Sales to third parties			3,845		4,420
	Production costs excluding taxes			3,083		2,433
	Exploration expenses incurred			-		-
	Taxes other than income			-		-
	Related income tax			-		-
	Results of producing activities			762		1,987
	Management’s judgment regarding the project’s capitalization of exploration well costs is based upon its current inability to estimate reserves. Currently, the project requires additional investment and approximately six months production history at substantially higher rates before an appropriate valuation of proved reserves may be made. The Company anticipates the following costs necessary to achieve proven reserve status of which E & P Co., LLC will be responsible for its interest accordingly:
	Description		Cost
	Addition of new saltwater disposal well			1,000,000
	Re-drill Well No. 1			1,000,000
	Replace pumps on Wells No. 4 and 5			200,000
	Proved reserves valuation			25,000
				-
	Net costs			2,225,000
	As of December 31, 2013 and 2012, the amounts of capitalized costs related to oil and gas producing activities was as follows:
			2013				2012
			Consolidated		Entity’s Share		Consolidated		Entity’s Share
					of Equity				of Equity
					Method				Method
					Investees				Investees
	Unproved oil and gas properties			19,009,407		19,009,407		18,351,693		18,351,693
	Proved oil and gas properties			-		-		-		-
	Accumulated depreciation, depletion and amortization, and valuation allowances			-		-		-		-
	Net capitalized costs			19,009,407		19,009,407		18,351,693		18,351,693
	The aging of amounts of capitalized well costs and number of projects are as follows:
Period Ending			Well Costs	Number of
December 31			Capitalized for the Period	Projects
2008			5,569,607	2
2009			2,986,906	2
2010			3,544,207	2
2011			5,285,613	2
2012			965,360	2
2013			657,714	2
Total			19,009,407	2
Costs Incurred In Oil And Gas Property Acquisition,
Exploration And Development
For The Years Ended December 31, 2013 And 2012
Consolidated Entries		2013		2012
Acquisition of Properties
Proved			-		-
Unproved			10,000		10,000
Exploration Costs			2,562		1,845
Development Costs			645,152		953,515
Entity’s Share of Equity Method Investees:
Acquisition of Properties
Proved			-		-
Unproved			10,000		10,000
Exploration Costs			2,562		1,845
Development Costs			645,152		953,515

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events [Text Block]	'
	Subsequent Events
	None noted.

SUMMARY_OF_ACCOUNTING_POLICIES1

SUMMARY OF ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2013
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.

MANAGEMENTS_DISCUSSION_AND_ANA1

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule Of Oil And Gas Properties Value Determination [Table Text Block]	'
	At December 31, 2013 and 2012, the Company’s Projects Under Development were $19,009,407 and $18,351,693, respectively.
	Entity	2013		2012
	Woodgate Energy Corporation (Parent)		-		-
	E & P Co., LLC (Subsidiary)		8,869,848		18,001,693
	Prestige O & G, LLC (Subsidiary)		10,139,559		350,000
	Total		19,009,407		18,351,693
Schedule Of Notes Payable [Table Text Block]	'
	At December 31, 2013 and 2012, the Company held Notes Payable consisting of $453,981 and $9,114,928, respectively.
	Entity	2013		2012
	Woodgate Energy Corporation (Parent)		-		-
	E & P Co., LLC (Subsidiary)		453,981		9,114,928
	Prestige O & G, LLC (Subsidiary)		-		-
	Total		453,981		9,114,928
Schedule of Accounts Payable and Accrued Liabilities [Table Text Block]	'
	At December 31, 2013 and 2012, the Company held Accounts Payable consisting of $266,835 and $698,760, respectively.
	Entity	2013		2012
	Woodgate Energy Corporation (Parent)		-		-
	E & P Co., LLC (Subsidiary)		266,835		698,760
	Prestige O & G, LLC (Subsidiary)		-		-
	Total		266,835		698,760
Results of Operations for Oil and Gas Producing Activities Disclosure [Table Text Block]	'
	The results of operations for producing activities shown below do not include earnings from nonoperating activities.
	Results of Operations for the Years Ending	2013		2012
	Revenue
	Sales to third parties		3,845		4,420
	Production costs excluding taxes		3,083		2,433
	Exploration expenses incurred		-		-
	Taxes other than income		-		-
	Related income tax		-		-
	Results of producing activities		762		1,987
Capitalized Exploratory Well Costs, Roll Forward [Table Text Block]	'
	The Company anticipates the following costs necessary to achieve proven reserve status of which E & P Co., LLC will be responsible for its interest accordingly:
	Description	Cost
	Addition of new saltwater disposal well		1,000,000
	Re-drill Well No. 1		1,000,000
	Replace pumps on Wells No. 4 and 5		200,000
	Proved reserves valuation		25,000
			-
	Net costs		2,225,000
Schedule of Oil and Gas In Process Activities [Table Text Block]	'
	As of December 31, 2013 and 2012, the amounts of capitalized costs related to oil and gas producing activities was as follows:
		2013				2012
		Consolidated		Entity’s Share		Consolidated		Entity’s Share
				of Equity				of Equity
				Method				Method
				Investees				Investees
	Unproved oil and gas properties		19,009,407		19,009,407		18,351,693		18,351,693
	Proved oil and gas properties		-		-		-		-
	Accumulated depreciation, depletion and amortization, and valuation allowances		-		-		-		-
	Net capitalized costs		19,009,407		19,009,407		18,351,693		18,351,693
Schedule of Productive Wells [Table Text Block]	'
	The aging of amounts of capitalized well costs and number of projects are as follows:
	Period Ending		Well Costs	Number of
	December 31		Capitalized for the Period	Projects
	2008		5,569,607	2
	2009		2,986,906	2
	2010		3,544,207	2
	2011		5,285,613	2
	2012		965,360	2
	2013		657,714	2
	Total		19,009,407	2
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]	'
	Costs Incurred In Oil And Gas Property Acquisition,
	Exploration And Development
	For The Years Ended December 31, 2013 And 2012
	Consolidated Entries	2013		2012
	Acquisition of Properties
	Proved		-		-
	Unproved		10,000		10,000
	Exploration Costs		2,562		1,845
	Development Costs		645,152		953,515
	Entity’s Share of Equity Method Investees:
	Acquisition of Properties
	Proved		-		-
	Unproved		10,000		10,000
	Exploration Costs		2,562		1,845
	Development Costs		645,152		953,515

GOING_CONCERN_Details_Textual

GOING CONCERN (Details Textual) (USD $)	12 Months Ended		103 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
Going Concern Disclosure [Line Items]	'	'	'
Net Income (Loss) Attributable to Parent	($2,278,844)	($592,816)	($5,886,327)
Development Stage Enterprise, Deficit Accumulated During Development Stage	($5,886,327)	($3,765,749)	($5,886,327)

STOCKHOLDERS_EQUITY_Details_Te

STOCKHOLDERS' EQUITY (Details Textual) (USD $)	0 Months Ended	1 Months Ended	12 Months Ended
	16-May-13	17-May-13	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Stockholder's Equity [Line Items]	'	'	'	'	'
Common Stock, Shares Authorized	'	'	100,000,000	100,000,000	'
Preferred Stock, Shares Authorized	'	'	20,000,000	'	'
Shares, Outstanding	20,000,000	'	'	'	'
Share Price	$0.00	'	'	'	'
Percentage of Common Stock Outstanding	'	'	94.50%	'	'
Development Stage Entities, Stock Issued, Value, Issued for Cash	'	'	$875	$2,000	'
Common Stock, Shares, Issued	'	'	47,345,000	20,000,000	'
Common Stock, Shares, Outstanding	'	'	47,345,000	20,000,000	'
Preferred Stock, Shares Issued	'	'	0	'	'
Preferred Stock, Shares Outstanding	'	'	0	'	'
Redemption of Common Stock	'	'	-1,950	'	'
Common Stock [Member]	'	'	'	'	'
Stockholder's Equity [Line Items]	'	'	'	'	'
Development Stage Entities, Stock Issued, Shares, Issued for Cash	'	'	8,750,000	20,000,000	'
Stock Redeemed or Called During Period, Shares	'	'	19,500,000	'	'
Shares, Outstanding	'	'	47,345,000	20,000,000	0
Development Stage Entities, Stock Issued, Value, Issued for Cash	'	9,250,000	875	2,000	'
Stock Issued During Period, Shares, New Issues	'	'	1,345,000	'	'
Redemption of Common Stock	$1,950	'	($1,950)	'	'
Subsidiaries [Member]	'	'	'	'	'
Stockholder's Equity [Line Items]	'	'	'	'	'
Stock Issued During Period, Shares, New Issues	'	'	36,750,000	'	'

MANAGEMENTS_DISCUSSION_AND_ANA2

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Oil and Gas In Process Activities [Line Items]	'	'
Projects Under Developments	$19,009,407	$18,351,693
Woodgate Energy Corporation (Parent)	'	'
Oil and Gas In Process Activities [Line Items]	'	'
Projects Under Developments	0	0
E & P Co., LLC (Subsidiary)	'	'
Oil and Gas In Process Activities [Line Items]	'	'
Projects Under Developments	8,869,848	18,001,693
Prestige O & G, LLC (Subsidiary)	'	'
Oil and Gas In Process Activities [Line Items]	'	'
Projects Under Developments	$10,139,559	$350,000

MANAGEMENTS_DISCUSSION_AND_ANA3

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Details 1) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Oil and Gas In Process Activities [Line Items]	'	'
Notes Payable	$453,981	$9,114,928
Woodgate Energy Corporation (Parent)	'	'
Oil and Gas In Process Activities [Line Items]	'	'
Notes Payable	0	0
E & P Co., LLC (Subsidiary)	'	'
Oil and Gas In Process Activities [Line Items]	'	'
Notes Payable	453,981	9,114,928
Prestige O & G, LLC (Subsidiary)	'	'
Oil and Gas In Process Activities [Line Items]	'	'
Notes Payable	$0	$0

MANAGEMENTS_DISCUSSION_AND_ANA4

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Details 2) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Oil and Gas In Process Activities [Line Items]	'	'
Accounts Payable	$266,835	$698,760
Woodgate Energy Corporation (Parent)	'	'
Oil and Gas In Process Activities [Line Items]	'	'
Accounts Payable	0	0
E & P Co., LLC (Subsidiary)	'	'
Oil and Gas In Process Activities [Line Items]	'	'
Accounts Payable	266,835	698,760
Prestige O & G, LLC (Subsidiary)	'	'
Oil and Gas In Process Activities [Line Items]	'	'
Accounts Payable	$0	$0

MANAGEMENTS_DISCUSSION_AND_ANA5

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Details 3) (USD $)	12 Months Ended		103 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
Revenue	'	'	'
Sales to third parties	$3,845	$4,420	$23,893
Production costs excluding taxes	3,083	2,433	39,659
Exploration expenses incurred	0	0	'
Taxes other than income	0	0	'
Related income tax	0	0	'
Results of producing activities	$762	$1,987	'

MANAGEMENTS_DISCUSSION_AND_ANA6

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Details 4) (USD $)	12 Months Ended
	Dec. 31, 2013
Oil and Gas In Process Activities [Line Items]	'
Addition of new saltwater disposal well	$1,000,000
Re-drill Well No. 1	1,000,000
Replace pumps on Wells No. 4 and 5	200,000
Proved reserves valuation	25,000
Net costs	$2,225,000

MANAGEMENTS_DISCUSSION_AND_ANA7

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Details 5) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Equity Method Investee [Member]	'	'
Oil and Gas In Process Activities [Line Items]	'	'
Unproved oil and gas properties	$19,009,407	$18,351,693
Proved oil and gas properties	0	0
Accumulated depreciation, depletion and amortization, and valuation allowances	0	0
Net capitalized costs	19,009,407	18,351,693
Consolidation, Eliminations [Member]	'	'
Oil and Gas In Process Activities [Line Items]	'	'
Unproved oil and gas properties	19,009,407	18,351,693
Proved oil and gas properties	0	0
Accumulated depreciation, depletion and amortization, and valuation allowances	0	0
Net capitalized costs	$19,009,407	$18,351,693

MANAGEMENTS_DISCUSSION_AND_ANA8

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Details 6) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
	Number	Number	Number	Number	Number	Number
Oil and Gas In Process Activities [Line Items]	'	'	'	'	'	'
Well Costs Capitalized for the Period	$2,225,000	'	'	'	'	'
Well Costs Capitalized for the Period, Gross	19,009,407	18,351,693	'	'	'	'
Number of Projects	2	'	'	'	'	'
Subsidiaries [Member]	'	'	'	'	'	'
Oil and Gas In Process Activities [Line Items]	'	'	'	'	'	'
Well Costs Capitalized for the Period	$657,714	$965,360	$5,285,613	$3,544,207	$2,986,906	$5,569,607
Number of Projects	2	2	2	2	2	2

MANAGEMENTS_DISCUSSION_AND_ANA9

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Details 7) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Consolidation, Eliminations [Member]	'	'
Acquisition of Properties	'	'
Proved	$0	$0
Unproved	10,000	10,000
Exploration Costs	2,562	1,845
Development Costs	645,152	953,515
Equity Method Investee [Member]	'	'
Acquisition of Properties	'	'
Proved	0	0
Unproved	10,000	10,000
Exploration Costs	2,562	1,845
Development Costs	$645,152	$953,515

Recovered_Sheet1

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Details Textual) (USD $)	12 Months Ended		103 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
Oil and Gas In Process Activities [Line Items]	'	'	'
Cash Equivalents, at Carrying Value	$736,647	$55,100	$736,647
Accounts Receivable, Related Parties, Current	0	562,438	0
Oil and Gas Sales Revenue	3,845	4,420	23,893
Net Income (Loss) Attributable to Parent	($2,278,844)	($592,816)	($5,886,327)
Earnings Per Share, Basic and Diluted	($0.06)	($0.02)	'