Rio Bravo Oil (SDGU) 10-K 14 Apr 14 2013 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Apr. 09, 2014	Jun. 30, 2013
Document Information [Line Items]	'	'	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Trading Symbol	'RIOB	'	'
Entity Registrant Name	'Rio Bravo Oil, Inc.	'	'
Entity Common Stock, Shares Outstanding	'	33,142,686	'
Entity Central Index Key	'0001502774	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Filer Category	'Smaller Reporting Company	'	'
Entity Public Float	'	'	$22,042,011

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
CURRENT ASSETS	'	'
Cash and cash equivalents	$0	$18,738
Other Receivables	5,742	6,747
Prepaid expenses	0	25,185
TOTAL CURRENT ASSETS	5,742	50,670
PROPERTY AND EQUIPMENT	'	'
Furniture, fixtures and equipment, net of accumulated depreciation	14,939	0
PROPERTY AND EQUIPMENT, NET	'	0
Deferred loan costs, net of amortization	128,578	244,565
Assets held for sale	7,590,352	18,311,958
TOTAL ASSETS	7,739,611	18,607,193
CURRENT LIABILITIES	'	'
Accounts payable	439,570	219,415
Accrued expenses	1,341,202	749,386
Advances payable - related party	90,704	90,704
Liabilities held for sale	799,290	440,149
Short term notes payable	6,427,330	1,935,000
Bridge notes payable	350,000	350,000
TOTAL CURRENT LIABILITIES	9,458,396	3,794,954
NON CURRENT LIABILITIES	'	'
Notes payable	613,829	3,113,829
Liabilities held for sale	3,517,861	3,256,724
TOTAL LIABILITIES	13,590,086	10,165,507
Commitments and contingencies	0	0
STOCKHOLDERS' EQUITY	'	'
Common Stock, $0.001 par value, 120,000,000. Authorized 32,502,657 and 32,391,657 issued and outstanding shares as of December 31, 2013 and 2012, respectively	32,502	32,391
Additional paid-in capital	6,190,688	6,079,799
Stockholders' deficit accumulated in the exploration stage	-17,957,915	-3,665,754
Stockholders' equity (deficit)	-11,731,475	2,449,686
TOTAL LIABILITIES AND STOCKHOLDERS' (DEFICIT) EQUITY	7,739,611	18,607,193
Former Director [Member]	'	'
CURRENT LIABILITIES	'	'
Loan from former director	3,332	3,332
Rio Bravo [Member]	'	'
CURRENT LIABILITIES	'	'
Rio Bravo assets purchase payable	6,968	6,968
Series A Preferred Stock [Member]	'	'
NON CURRENT LIABILITIES	'	'
REDEEMABLE SERIES PREFERRED STOCK	5,389,000	5,500,000
Series B Preferred Stock [Member]	'	'
STOCKHOLDERS' EQUITY	'	'
Series B Preferred Stock, $0.001 par value, 5,000,000. Authorized, 3,250,000 issued and outstanding shares of December 31, 2013 and 2012, respectively, liquidation value of $3,250,000	3,250	3,250
Stockholders' equity (deficit)	3,250	3,250
Series C Preferred Stock [Member]	'	'
NON CURRENT LIABILITIES	'	'
REDEEMABLE SERIES PREFERRED STOCK	$492,000	$492,000

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS [Parenthetical] (USD $)	Dec. 31, 2013	Dec. 31, 2012
Common Stock, par value (in dollars per share)	$0.00	$0.00
Common Stock, Authorized	120,000,000	120,000,000
Common Stock, Shares Issued	32,502,657	32,391,657
Common Stock, Shares Outstanding	32,502,657	32,391,657
Series B Preferred Stock [Member]	'	'
Preferred Stock, Par or Stated Value Per Share (in dollars per share)	$0.00	$0.00
Preferred Stock, Shares Authorized	5,000,000	5,000,000
Preferred Stock, Shares Issued	3,250,000	3,250,000
Preferred Stock, Shares Outstanding	3,250,000	3,250,000
Preferred Stock, Liquidation Preference, Value	$3,250,000	$3,250,000

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	12 Months Ended		43 Months Ended	1 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Feb. 14, 2012	Feb. 14, 2012
				Predecessor [Member]	Predecessor [Member]
					Related Party [Member]
REVENUES AND GAINS	'	'	'	'	'
Revenues from sale of oil and gas	$120,153	$101,556	$221,709	$0	'
OPERATING EXPENSES:	'	'	'	'	'
Leasehold operating and workover expense	1,485,201	799,386	2,284,587	0	'
General and administrative	614,856	817,872	1,494,255	108,972	0
Professional fees	605,316	1,273,430	1,878,746	54,649	'
Impairment	'	'	'	0	'
Depreciation, depletion, amortization and impairment expense	10,730,753	97,484	10,828,237	3,311	'
Total operating expenses	13,436,126	2,988,172	16,485,825	166,932	'
LOSS FROM OPERATIONS	-13,315,973	-2,886,616	-16,264,116	-166,932	'
OTHER INCOME AND EXPENSE	'	'	'	'	'
Other income	1,563	0	1,563	'	'
Interest income - related party	'	'	'	'	0
Interest expense	-812,751	-567,841	-1,380,737	0	'
Total other income (expense)	-811,188	-567,841	-1,379,174	0	'
NET LOSS	-14,127,161	-3,454,457	-17,643,290	-166,932	'
PREFERRED DIVIDENDS	165,000	144,375	309,375	0	'
NET LOSS TO COMMON STOCKHOLDERS	($14,292,161)	($3,598,832)	($17,952,665)	($166,932)	'
Basic and diluted loss per common share (in dollars per share)	($0.44)	($0.08)	($0.29)	$0	'
Basic and diluted weighted average common shares outstanding (in shares)	32,497,438	47,414,763	61,837,395	95,264,795	'

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended		43 Months Ended	1 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Feb. 14, 2012
				Predecessor [Member]
CASH FLOWS FROM OPERATING ACTIVITES	'	'	'	'
Net loss	($14,127,161)	($3,454,457)	($17,643,290)	($166,932)
Adjustments to reconcile net loss to cash used in operations	'	'	'	'
Depreciation, depletion, amortization and impairment	10,730,753	97,484	10,828,237	3,311
Non cash interest expense	377,124	304,630	681,899	0
Impairment of investment in Eagle Ford	40,000	0	40,000	'
Stock based compensation	0	119,650	119,650	'
General and administrative expenses advanced by related party	'	'	'	0
Changes in assets and liabilities	'	'	'	'
Other receivables	'	'	'	0
Prepaid expenses	26,196	-2,158	23,186	-12,175
Accounts payable	869,296	-271,409	597,887	0
Accrued expenses	426,810	294,419	730,026	0
NET CASH USED BY OPERATIONS	-1,656,982	-2,911,841	-4,622,405	-175,796
CASH FLOWS FROM INVESTING ACTIVITIES	'	'	'	'
Capital expenditures - property, plant and equipment and oil and gas property	-24,086	-1,631,081	-1,655,167	-30,000
Cash paid to acquire Pan American Oil Company, LLC, net of cash acquired	'	-495,656	-495,656	615,250
Cash paid to acquire leasehold interests from Eagle Ford Oil Co	-40,000	-1,094,193	-1,134,193	-409,506
CASH FLOW USED IN INVESTING ACTIVITIES	-64,086	-3,220,930	-3,285,016	175,744
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'	'
Proceeds from stockholder loans	1,267,601	0	1,467,601	0
Repayment of stockholder loan	0	-200,000	-200,000	0
Proceeds from debt issuance	'	5,188,704	5,188,704	0
Proceeds from director loan	0	0	3,332	'
Proceeds from other loans and advances	445,639	0	445,639	'
Loan fees paid	0	-360,000	-360,000	0
Loan repayments	-10,910	-206,943	-217,853	'
Bridge notes proceeds	'	'	'	245,000
Repayments of bridge loans	'	-1,550,000	-1,550,000	-200,000
Proceeds from sale of common stock and warrants net of offering costs paid	0	2,615,248	2,637,998	0
Proceeds from Series C preferred stock offering	0	492,000	492,000	'
Payment of Series A offering costs	'	'	'	0
CASH PROVIDED BY FINANCING ACTIVITIES	1,702,330	5,979,009	7,907,421	45,000
Increase (decrease) in cash and cash equivalents	-18,738	-153,762	0	44,948
Cash and cash equivalents, beginning of year	18,738	172,500	0	5,159
Cash and cash equivalents, end of year	0	18,738	0	50,107
Cash paid for interest	$0	$19,167	$19,167	$0

CONSOLIDATED_STATEMENT_OF_STOC

CONSOLIDATED STATEMENT OF STOCKHOLDERS' (DEFICIT) EQUITY (USD $)	Total	Series B Preferred Stock [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Subscription Receivable [Member]	Retained Earnings [Member]
Balance at inception at Jun. 08, 2010	$0	$0	$0	$0	$0	$0
Balance at inception (in shares) at Jun. 08, 2010	'	0	0	'	'	'
June 21, 2010, Common shares issued for cash at $0.001	2,500	0	75,000	0	0	-72,500
June 21, 2010, Common shares issued for cash at $0.001 (in shares)	'	0	75,000,000	'	'	'
September 29, 2010, Common shares issued for cash at $0.03	20,250	0	20,250	0	0	0
September 29, 2010, Common shares issued for cash at $0.03 (in shares)	'	0	20,250,000	'	'	'
Net loss	-941	0	0	0	0	-941
Balance at Sep. 30, 2010	21,809	0	95,250	0	0	-73,441
Balance (in shares) at Sep. 30, 2010	'	0	95,250,000	'	'	'
Net loss	-19,346	0	0	0	0	-19,346
Balance at Sep. 30, 2011	2,463	0	95,250	0	0	-92,787
Balance (in shares) at Sep. 30, 2011	'	0	95,250,000	'	'	'
Net loss	-40,635	'	'	'	'	-40,635
Balance at Dec. 31, 2011	-38,172	0	95,250	0	0	-133,422
Balance at inception (in shares) at Dec. 31, 2011	'	0	95,250,000	'	'	'
Share cancelation	0	0	-66,500	0	0	66,500
Share cancelation (in shares)	'	0	-66,500,010	'	'	'
Balance after cancelation	-38,172	'	28,750	0	'	-66,922
Balance after cancelation (in shares)	'	'	28,749,990	'	'	'
Unit offering of common stock and warrants	2,656,249	'	3,541	2,652,708	'	'
Unit offering of common stock and warrants (in shares)	'	'	3,541,667	'	'	'
Unit offering of common stock and warrants subscribed to	0	'	'	500,000	-500,000	'
Cancellation of common stock and warrants subscribed to	0	'	'	-500,000	500,000	'
Unit offering cost	-306,626	'	'	-306,626	'	'
Stock issuable Michael Garnick	750	'	'	750	'	'
Series B issued - Numa Luling acquisition	3,466,667	3,250	0	3,463,417	0	'
Series B issued - Numa Luling acquisition (in shares)	'	3,250,000	0	'	'	'
Common stock issued for investor advisor services	86,000	'	100	85,900	'	'
Common stock issued for investor advisor services (in shares)	'	'	100,000	'	'	'
Warrants - issued for consulting services	33,650	'	'	33,650	'	'
Beneficial feature of convertible notes	150,000	'	'	150,000	'	'
Dividends	-144,375	'	'	'	'	-144,375
Net loss	-3,454,457	0	0	0	0	-3,454,457
Balance at Dec. 31, 2012	2,449,686	3,250	32,391	6,079,799	0	-3,665,754
Balance (in shares) at Dec. 31, 2012	'	3,250,000	32,391,657	'	'	'
Series B issued - Numa Luling acquisition (in shares)	'	3,250,000	'	'	'	'
Conversion of Series A	111,000	'	111	110,889	'	'
Conversion of Series A (in shares)	'	'	111,000	'	'	'
Dividends	-165,000	'	'	'	'	-165,000
Net loss	-14,127,161	'	'	'	'	-14,127,161
Balance at Dec. 31, 2013	($11,731,475)	$3,250	$32,502	$6,190,688	$0	($17,957,915)
Balance (in shares) at Dec. 31, 2013	'	3,250,000	32,502,657	'	'	'

CONSOLIDATED_STATEMENT_OF_STOC1

CONSOLIDATED STATEMENT OF STOCKHOLDERS' (DEFICIT) EQUITY [Parenthetical] (USD $)	Sep. 29, 2010	Jun. 21, 2010
Share Price	$0.03	$0.00

BASIS_OF_PRESENTATION_AND_GOIN

BASIS OF PRESENTATION AND GOING CONCERN	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Organization, Consolidation, Basis of Presentation, Business Description and Accounting Policies [Text Block]	'
	NOTE 1 - BASIS OF PRESENTATION AND GOING CONCERN
	Nature of Operations and Presentation
	These financial statements include the accounts of Rio Bravo Oil, Inc. (the “Company”), formerly Soton Holdings Group, Inc., which was formed on June 9, 2010 in the state of Nevada and its wholly-owned subsidiary Pan American Oil Company, LLC. Except where the context otherwise requires, the “Company,” “we,” “our” and “us” refers to Rio Bravo Oil, Inc. and our wholly-owned subsidiary Pan American Oil Company, LLC.
	As described in more detail later in this document, the Company acquired Pan American Oil Company, LLC on February 14, 2012. Prior to that acquisition the Company was a shell company with limited or no operations. Under Securities and Exchange Commission (the “SEC”) rules when a registrant succeeds to substantially all of the business (or a separately identifiable line of business) of another entity (or group of entities) and the registrant's own operations before the succession appear insignificant relative to the operations assumed or acquired - the registrant is required to present financial information for the acquired entity (the “predecessor”) for all comparable periods prior to the date of acquisition being presented before the succession.
	Therefore we are providing certain additional information in our financial statements regarding the predecessor businesses for periods prior to February 14, 2012. Pan American Oil Company, LLC, is considered a predecessor, Also, Pan American Oil Company, LLC purchased certain oil and gas leasehold interests from Rio Bravo Oil, LLC on February 13, 2012 prior to being acquired by the Company and therefore those leasehold interests are also considered a predecessor. Collectively, Pan American Oil Company, LLC and the leasehold interests acquired from Rio Bravo Oil, LLC is referred to as the “Predecessor Business” This financial information (for which intercompany transactions between the predecessors have been eliminated) for the period prior to February 14, 2012 is labeled “Predecessor Business” and the Company has placed a heavy black line between it and the Company’s (also referred to as the successor) information to differentiate it from the Company’s financial information.
	Going Concern
	The Company has incurred significant operating losses since its inception and has an accumulated deficit at December 31, 2013 of approximately $21.6 million. In addition, as of December 31, 2013, the Company had a working capital deficit of approximately $9.45 million and is currently unable to satisfy it’s obligations when they come due. These circumstances raise substantial doubt about the Company’s ability to continue as a going concern. Implementation of the Company’s plans and its ability to continue as a going concern depend upon its securing substantial additional financing.
	The Company has only enough cash to operate into May 2014. Management’s plans include efforts to obtain additional capital and to seek out new opportunities in the oil and gas space or to abandon the oil and gas industry and to seek out other industries in which it could find possible acquisition targets, although no assurances can be given about the Company’s ability to obtain such capital or to acquire other businesses. If the Company is unable to obtain adequate additional financing or a suitable candidate to merge with, it will be unable to continue its drilling plans and other activities and may be forced to cease operations. The consolidated financial statements presented herein do not include any adjustments that might result from the outcome of this uncertainty.

MERGER_WITH_PAN_AMERICAN_OIL_C

MERGER WITH PAN AMERICAN OIL COMPANY, LLC	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Business Combination Disclosure [Text Block]	'
	NOTE 2 - MERGER WITH PAN AMERICAN OIL COMPANY, LLC
	On February 14, 2012, the Company completed the acquisition of all of the outstanding member interests of Pan American Oil Company, LLC (“Pan Am”) at which time Pan Am became a wholly owned subsidiary of the Company. The purchase price of the member interests of Pan Am was 5,500,000 shares of Series A Preferred stock (see Note 8) plus the assumption of certain liabilities of Pan Am. Liabilities that were not assumed by the Company primarily consisted of a liability to deliver $500,000 worth of preferred shares, from an earlier acquisition by Pan Am (see below). This liability was distributed to the members of Pan Am immediately prior to the acquisition of Pan Am by the Company. The acquisition of Pan Am allowed the Company to enter the oil and gas industry and gain access to oil and gas leaseholds covering approximately 4,500 acres gross (2,143 net) within the Edwards formation in Texas. The Company acquired an approximate 63.5%/57% working interest (before/after pay out) and approximate 38% net revenue interest (after pay out) in the Edwards formation leaseholds in Caldwell and Guadeloupe counties in Texas. Immediately following the acquisition the Company changed its year end to December 31 to conform with that of Pan Am.
	Immediately prior to the merger with the Company, Pan Am consummated an acquisition of oil and gas leasehold interests in the Edwards formation from Rio Bravo Oil, LLC (“Rio LLC”), a company with common ownership and control with Pan Am. The purchase price of the leasehold interests was $1.6 million which consisted of approximately $966,000 of cash and payment of expenses on behalf of Rio LLC, a payable to Rio LLC of approximately $120,000 (of which $113,000 was paid in 2012) and assumption of a payable to the operator of the Edwards formation leaseholds of approximately $364,000. Because the two companies were under common control, the acquisition of these assets were reflected at their historical basis of Rio LLC by Pan Am, with the excess consideration being treated as a distribution to a member of Rio LLC as reflected under the Predecessor Business caption on the balance sheet presented in this document. As a result of application of the purchase method of accounting, which is based on the amount of consideration paid, these same assets are reflected using a stepped up basis in the Company’s balance sheet. Thus the Company’s financial statements from the periods prior to the transaction date are not directly comparable to the financial statements for periods subsequent to the transaction date.
	Under the purchase method of accounting, the Company assets acquired and liabilities assumed are recorded at their respective fair values as of the transaction date. In connection with the merger, the consideration paid, and the assets acquired and liabilities assumed, recorded at fair value on the date of acquisition, are summarized in the following tables:
		In thousands
	Net assets acquired
	Cash	$	50
	Prepaids		22
	Proved oil and gas property		7,370
	Furniture, fixtures and equipment		292
	Other receivables		948
		$	8,682
	Liabilities
	Accounts payable & accrued expenses	$	415
	Loans payable		87
	Bridge notes payable		1,900
	Other liabilities		770
	Asset retirement obligations		10
		$	3,182
	Net identifiable assets/consideration paid	$	5,500
	Initial accounting for the acquisition was incomplete and provisional amounts were recorded in the initial interim periods after the acquisition. The amounts in the table above reflect updated information. The changes subsequent to the provisional information were a reduction of prepaid expenses of $150,000 and a corresponding reduction in accounts payable of $150,000.
	Unaudited Pro Forma Statements of Operations Data
	The following unaudited pro forma statement of operations data presents the combined results of the Company as if its acquisition of Pan Am had occurred on January 1, 2012.
	The unaudited pro forma information presented below is based on various assumptions and presented for comparative purposes only and is not necessarily indicative of the results of operations that actually would have been achieved if the acquisition had taken place at the beginning of 2012.
	Pro forma net sales	$	101,556
	Pro forma net loss to common stockholders	$	-3,765,764
	Pro forma basic and diluted loss per share	$	-0.08

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Significant Accounting Policies [Text Block]	'
	NOTE 3 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	Principles of Consolidation
	The consolidated financial statements included herewith include the accounts of the Company and its wholly-owned subsidiary. All significant inter-company balances and transactions have been eliminated in consolidation.
	Cash and cash equivalents
	The Company considers all highly liquid instruments with original maturity of less than 90 days to be cash equivalents.
	Exploration Stage Enterprise
	The Company has been devoting most of its efforts to exploring for and developing its oil and gas assets and, consequently, meets the definition of An Exploration Stage Enterprise, under the Accounting Standards Codification “Accounting and Reporting for Development Stage Enterprises.” Certain additional financial information is required to be included in the financial statements for the period from inception of the Company to the current balance sheet date.
	Furniture, Fixtures & Equipment
	Property and equipment are stated at cost less accumulated depreciation and are depreciated using the straight-line method over the assets’ estimated useful lives. Principal useful lives are as follows:
	Oil field equipment	7 years
	Normal maintenance and repairs for property and equipment are charged to expense as incurred, while significant improvements are capitalized.
	In accordance with authoritative guidance on accounting for the impairment or disposal of long-lived assets, as set forth in Topic 360 of the Financial Accounting Standards Board Accounting Standards CodificationTM (the “FASC”), the Company assesses the recoverability of the carrying value of its non-oil and gas long-lived assets when events occur that indicate an impairment in value may exist. An impairment loss is indicated if the sum of the expected undiscounted future net cash flows is less than the carrying amount of the assets. If this occurs, an impairment loss is recognized for the amount by which the carrying amount of the assets exceeds the estimated fair value of the asset.
	Oil and Gas Properties
	The Company follows the full cost method of accounting for oil and natural gas operations. Under this method all productive and nonproductive costs incurred in connection with the acquisition, exploration, and development of oil and natural gas reserves are capitalized on a country-by-country basis into an individual country “cost pool.” The Company has operations in the United States and, consequently, only has one cost pool. No gains or losses are recognized upon the sale or other disposition of oil and natural gas properties except in transactions that would significantly alter the relationship between capitalized costs and proved reserves. The costs of unevaluated oil and natural gas properties are excluded from the amortizable base until the time that either proven reserves are found or it has been determined that such properties are impaired. As properties become evaluated, the related costs are transferred to the proved oil and natural gas properties cost pool using full cost accounting.
	Under the full cost method the net book value of oil and natural gas properties, less related deferred income taxes, may not exceed the estimated after-tax future net revenues from proved oil and natural gas properties, discounted at 10% (the “Ceiling Limitation”). In arriving at estimated future net revenues, estimated lease operating expenses, development costs, and certain production-related and ad valorem taxes are deducted. In calculating future net revenues, prices and costs are held constant indefinitely, except for changes that are fixed and determinable by existing contracts. Prices are determined using a simple arithmetic average of the first day of each month during the most recent twelve month period presented herein. The net book value is compared to the Ceiling Limitation on a quarterly and yearly basis. The excess, if any, of the net book value above the Ceiling Limitation is charged to expense in the period in which it occurs and is not subsequently reinstated.
	Unit-of-production depletion is applied to capitalized costs of the full cost pool. Unit-of-production rates are based on the amount of proved reserves (both developed and undeveloped) of oil, gas and other minerals that are estimated to be recoverable from existing facilities using current operating methods.
	The costs of investments in unproved properties and portions of costs associated with major development projects are excluded from the depreciation, depletion and amortization calculation until the project is evaluated.
	Unproved property costs include leasehold costs, seismic costs and other costs incurred during the exploration phase. In areas where proved reserves are established, significant unproved properties are evaluated periodically, but not less than annually, for impairment. If a reduction in value has occurred, these property costs are considered impaired and are transferred to the related full cost pool. Unproved properties whose acquisition costs are not individually significant are aggregated, and the portion of such costs estimated to be ultimately nonproductive, based on experience, and is amortized to the full cost pool over an average holding period.
	Use of Estimates
	The preparation of the Company’s financial statements in accordance with US GAAP 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. Management believes that the following material estimates affecting the financial statements could significantly change in the coming year.
	The most significant estimates pertain to proven oil and natural gas reserves and related cash flow estimates used in impairment tests of long-lived assets, estimates of future development, dismantlement and abandonment costs. Certain of these estimates require assumptions regarding future costs and expenses and future production rates. Actual results could differ from those estimates.
	The Company’s revenue, profitability and future growth are substantially dependent upon the prevailing and future prices for oil and natural gas, which are dependent upon numerous factors beyond their control such as economic, political and regulatory developments and competition from other energy sources. The energy markets have historically been very volatile and there can be no assurance that oil and natural gas prices will not be subject to wide fluctuations in the future. A substantial or extended decline in oil and natural gas prices could have a material adverse effect on the Company’s financial position, results of operations, cash flows and quantities of oil and natural gas reserves that may be economically produced.
	Estimates of oil and natural gas reserves and their values, future production rates and future costs and expenses are inherently uncertain for numerous reasons, including many factors beyond the Company’s control. Reservoir engineering is a subjective process of estimating underground accumulations of oil and natural gas that cannot be measured in an exact manner. The accuracy of any reserve estimate is a function of the quality of data available and of engineering and geological interpretation and judgment. In addition, estimates of reserves may be revised based on actual production, results of subsequent exploration and development activities, prevailing commodity prices, operating cost and other factors. These revisions may be material and could materially affect future depletion, depreciation and amortization expense, dismantlement and abandonment costs, and impairment expense.
	Revenue Recognition
	Revenues are recognized when hydrocarbons have been delivered, the customer has taken title and payment is reasonably assured.
	Taxes Associated with Revenue Producing Transactions
	The Company reports taxes assessed by state, local and U.S. federal governmental authorities from the production and sale of hydrocarbons on a line item under operating expenses.
	Income Taxes
	Income taxes are provided for the tax effects of transactions reported in the financial statements and consist of taxes currently due plus deferred taxes related primarily to differences between the bases of certain assets and liabilities for financial and tax reporting. The deferred taxes represent the future tax return consequences of those differences, which will either be deductible or taxable when the assets and liabilities are recovered or settled. Valuation allowances are provided against deferred tax assets if it is more likely than not that the deferred asset will not be realized.
	The Company follows the guidance of FASC 740 Income Taxes, Accounting for Uncertainty in Income Taxes, which prescribes a comprehensive model for how a company should measure, recognize, present, and disclose in its financial statements uncertain tax positions that the company has taken or expects to take on income tax returns.
	The Company recognizes the tax benefits from uncertain tax positions only if it is more likely than not that the tax position will be sustained on examination. The tax benefits recognized in the financial statements from such positions are measured based on the largest benefit that has a greater than 50% likelihood of being realized upon ultimate settlement. As of December 31, 2013 and 2012, the Company has not taken any uncertain tax positions.
	Asset Retirement Obligations
	The Company provides for future asset retirement obligations on its resource properties and facilities based on estimates established by current legislation and industry practices. The asset retirement obligation is initially measured at fair value and capitalized as an asset retirement cost that is amortized on a straight line 15 year basis. The obligation is accreted through interest expense until it is expensed and or settled. The fair value of the obligation is estimated based on recent operations in the area and is then accreted using an expected inflation rate for oil field service costs. The Company recognizes revisions to either the timing or amount of the original estimate as increases or decreases to the asset retirement obligation.
	The significant assumptions used to develop the expected liability during the period are as follows:
	Average cost to remediate individual well sites: $4,000 to $7,000 (net to our interest)
	Average gross salvage value expected from individual well sites remediated: $0 (net)
	Expected inflation rate for oil field service costs: 5%
	Risk weighted cost of credit: 8%
	Average time to abandonment: 20 years
	Actual retirement costs will be recorded against the obligation when incurred. Any difference between the recorded asset retirement obligation and the actual retirement costs incurred is recorded as a gain or loss in the settlement period.
	Concentrations
	Upon acquisition of oil and gas field interests, the Company also became a party to joint operating agreements (“JOA’s”) that define the rights and responsibilities third party operators and passive interest holders. Under the JOA, the third party operator is responsible for acquiring customers to sell the oil and gas produced and to either performing or contracting out to other third parties to perform services necessary to continue and maintain undeveloped acreage. Currently all of the Company’s leasehold interests have as their third party operator Eagle Ford Oil Co. Inc. which is controlled by the former managing member of both Pan Am Oil Co., LLC and Rio Bravo Oil, LLC.
	Concentrations of Market Risk
	The future results of the company’s oil and natural gas operations will be affected by the market prices of oil and natural gas. The availability of a ready market for oil and natural gas products in the future will depend on numerous factors beyond the control of the Company, including weather, imports, marketing of competitive fuels, proximity and capacity of oil and natural gas pipelines and other transportation facilities, any oversupply or undersupply of oil, natural gas and liquid products, the regulatory environment, the economic environment, and other regional and political events, none of which can be predicted with certainty.
	The Company operates in the exploration, development and production sector of the oil and gas industry. While certain of these customers and joint venture partners are affected by periodic downturns in the economy in general or in their specific segment of the oil and natural gas industry, the Company believes that its level of credit-related losses due to such economic fluctuations has been and will continue to be immaterial to the Company’s results of operations over the long-term.
	Concentrations of Credit Risk
	Financial instruments that potentially subject the Company to significant concentrations of credit risk consist primarily of cash. During the year the amount of bank deposits that exceeded Federal Deposit Insurance Corporation (“FDIC”) insurance can be material.
	Fair Value
	As defined in authoritative guidance, 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 at the measurement date (“exit price”). To estimate fair value, the Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable.
	The authoritative guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities ("Level 1" measurements) and the lowest priority to unobservable inputs ("Level 3" measurements). The three levels of the fair value hierarchy are as follows:
	Level 1 - Observable inputs such as quoted prices in active markets at the measurement date for identical, unrestricted assets or liabilities.
	Level 2 - Other inputs that are observable, directly or indirectly, such as quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability.
	Level 3 - Unobservable inputs for which there is little or no market data and which the Company makes its own assumptions about how market participants would price the assets and liabilities.
	In instances in which multiple levels of inputs are used to measure fair value, hierarchy classification is based on the lowest level input that is significant to the fair value measurement in its entirety. The Company's assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment, and considers factors specific to the asset or liability.
	Net Loss Per Share
	Basic loss per share is calculated based on the weighted-average number of outstanding common shares. Diluted loss per share is calculated based on the weighted-average number of outstanding common shares plus the effect of dilutive potential common shares, using the treasury stock method. The Company’s calculation of diluted net loss per share excludes potential common shares as of December 31, 2013 and 2012 as the effect would be anti-dilutive (i.e. would reduce the loss per share). At December 31, 2013, warrants and preferred stock that were convertible into 12,639,453 shares of common stock were not included in the net loss per share calculation.
	In accordance with SEC Accounting Series Release 280, the Company computes its income or loss applicable to common stock holders by subtracting dividends on preferred stock, including undeclared or unpaid dividends if cumulative, from it reported net loss and reports the same on the face of its statement of operations.
	Recent Accounting Pronouncements
	In the first quarter of 2013, the Company adopted guidance issued by the Financial Accounting Standards Board (the “FASB”) that simplifies how an entity tests indefinite-lived intangibles for impairment. The amended guidance allows companies to first assess qualitative factors to determine whether it is more-likely-than-not that an indefinite-lived intangible asset is impaired as a basis for determining whether it is necessary to perform the quantitative impairment test. The adoption of this guidance had no impact on the Company’s financial position and results of operations.
	During the fiscal first quarter of 2013, the Company adopted the FASB guidance related to additional reporting and disclosure of amounts reclassified out of accumulated other comprehensive income (AOCI). Under this new guidance, companies are required to disclose the effect of significant reclassifications out of AOCI on the respective line items on the income statement if the amount being reclassified is required under U.S. generally accepted accounting principles (GAAP) to be reclassified in its entirety to net income. For other amounts that are not required under GAAP to be reclassified in their entirety to net income in the same reporting period, an entity is required to cross-reference other disclosures required under GAAP that provide additional details about those amounts. This update became effective for annual and interim reporting periods for fiscal years beginning after December 15, 2012. The adoption of this guidance had no impact on the Company’s financial position and results of operations.

ACQUISITION_OF_LEASEHOLD_INTER

ACQUISITION OF LEASEHOLD INTERESTS FROM NUMA LULING, LLC AND EAGLE FORD OIL CO, INC.	12 Months Ended
	Dec. 31, 2013
Acquisition Of Leasehold Interests [Abstract]	'
Acquisition Of Leasehold Interests [Text Block]	'
	NOTE 4 – ACQUISITION OF LEASEHOLD INTERESTS FROM NUMA LULING, LLC AND EAGLE FORD OIL CO, INC.
	In June 2012, the Company completed the acquisition of all of the leasehold interests held by Numa Luling, LLC (“Numa”). The purchase price of the leasehold interests acquired from Numa was 3,250,000 shares of Series B Preferred stock (see Note 8) plus the assumption of certain liabilities of Numa. The stock was valued at its then fair value upon issuance at $3,466,667. The acquisition of Numa increased the Company’s ownership interest in the Edwards formation leaseholds covering approximately 4,500 acres gross (2,143 net) in Texas. The Company acquired an approximate 25% working interest and approximate 18.75% net revenue interest (after pay out) in the Edwards formation leaseholds in Caldwell and Guadeloupe counties in Texas. The results of operation of Numa are included herein starting on June 1, 2012.
	In May 2012, the Company completed the acquisition of 80% of the leasehold interests and approximately 500 wells held by Eagle Ford Oil Co, Inc. (“Eagle Ford”). The purchase price of the leasehold interests and wells acquired was approximately $2 million in cash plus a note for $225,000 plus the assumption of certain liabilities. Prior to the acquisition, Pan Am advanced Eagle Ford approximately $906,000 which was deducted from the $2 million cash payment required to be made to Eagle Ford. The Company assumed Eagle Ford’s liabilities to the previous leaseholders, the bankruptcy estate of Caltex Swabbing Co. Those liabilities were primarily $295,000 of the original upfront cash purchase price paid that was still owing to the bankruptcy estate and “Option B” liability that requires the Company to pay to the bankruptcy estate $5,000 per well drilled for the first 200 wells and in the event that 200 wells are not drilled on or before March 16, 2016, the difference between $1 million and the amount paid per well becomes immediately due. In 2012, the Company paid $171,798 of the $295,000 assumed liability. The Company recorded the fair value amount of the debt at the time of acquisition in the amount of $726,921 using an 8% risk free rate. The Company acquired 80% working interest and approximate 60% net revenue interest in the same acreage as the Edwards formation, but for all depths below and above the Edwards formation. Eagle Ford retained the third party operating rights to the Fields and also has 20% of its interest carried by the Company for all drilling and swabbing operations. The swabbing operation currently holds production for the entire leasehold. The results of operation for Eagle Ford are included herein starting on April 1, 2012.
	Under the purchase method of accounting, the Company assets acquired and liabilities assumed are recorded at their respective fair values as of the transaction date. In connection with the merger, the consideration paid, and the assets acquired and liabilities assumed, recorded at fair value on the date of acquisition, are summarized in the following tables:
		In thousands
	Net assets acquired
	Cash	$	-
	Prepaids		182
	Proved oil and gas property		8,500
	Furniture, fixtures and equipment		376
		$	9,058
	Liabilities
	Accounts payable and accrued expenses	$	-
	Loans payable		295
	Other liabilities		727
	Asset retirement obligations		2,345
		$	3,367
	Net identifiable assets/consideration paid	$	5,691
	Initial accounting for the acquisition was incomplete and provisional amounts were recorded in the initial interim periods after the acquisition. The amounts in the table above reflect updated information. The changes subsequent to the provisional information were a reduction of prepaid expenses of $17,000 and a corresponding increase in proved oil and gas property of $17,000.
	Unaudited Pro Forma Statements of Operations Data
	The following unaudited pro forma statement of operations data presents the combined results of the Company as if its acquisition of Numa and EF had occurred on January 1, 2012.
	The unaudited pro forma information presented below is based on various assumptions and presented for comparative purposes only and is not necessarily indicative of the results of operations that actually would have been achieved if the acquisition had taken place at the beginning of 2012.
	Pro forma net sales	$	-
	Pro forma net loss to common stockholders	$	-3,772,266
	Pro forma basic and diluted loss per share	$	-0.08

DISPOSITION_AND_IMPAIRMENT_OF_

DISPOSITION AND IMPAIRMENT OF OIL AND GAS INTERESTS	12 Months Ended
	Dec. 31, 2013
Disposition And Impairment Of Oil And Gas Interests [Abstract]	'
Disposition And Impairment Of Oil And Gas Interests [Text Block]	'
	NOTE 5 – DISPOSITION AND IMPAIRMENT OF OIL AND GAS INTERESTS
	In the third quarter of 2013, the Company entered into an agreement to acquire Eagle Ford. The purchase price was $300,000 plus the assumption of all of its outstanding liabilities. Acquisition of Eagle Ford would increase the Company’s ownership in the leasehold interests acquired from an 80% working interest to a 100% working interest and it would also give them the ability to act as operator for their own and other leasehold interest should they choose to do so. The Company was required to pay $25,000 at close and then another $125,000 on or before September 30, 2013 with the final $150,000 due on or before October 31, 2013. The Company was only able to make the first $25,000 payment and a further $15,000 payment in the fourth quarter. By year end, the deal was abandoned and the Company wrote off the $40,000 investment. The failure to obtain financing for the deal led the Company at the end of 2013 to approve a plan to attempt to sell substantially all of its oil and gas assets in order to reduce its cash flow deficit from its leasehold working interests.
	In February 2014, the Company entered into a sale agreement with Eagle Ford, the current operator for its oil field interests, such that the Company sold the entirety of its working and net revenue interests in all of its oil field leaseholds and also sold all of its salvage equipment obtained through its acquisitions (see Notes 2 and 4). In addition, Eagle Ford agreed to take over all of the Company’s payables related to the leasehold interests and all of the remaining obligations incurred by the Company when it acquired its leasehold interests from Eagle Ford back in 2012. As consideration Eagle Ford issued a note to the Company in the amount of $500,000 plus a 10% carried working interest in the oil field leaseholds sold to Eagle Ford. The 10% carried working interest is subject to the existing 25% overriding royalty interests that exist on the leaseholds. The Company’s carried working interest means they are not obligated for any cash calls for any drilling or re-work drilling activity and are only obligated for 10% of the leasehold operating expenses. Because the plan for the sale of the assets was in place as of December 31, 2013, these financial statements show all of the assets and liabilities at all balance sheet dates presented as “held for sale”.
	The following table shows the assets and liabilities held for sale as of December 31:
		2013	2012
	ASSETS HELD FOR SALE
	Proved oil and gas property	15,888,126	17,741,096
	Unproved oil and gas property	1,862,117	-
	Accumulated depletion and impairment	-10,657,849	-24,377
	Net oil and gas properties	7,092,394	17,716,719
	Well Equipment	668,349	668,346
	Accumulated depreciation	-170,391	-73,107
	Net property, plant and equipment	497,958	595,239
	Total assets held for sale	7,590,352	18,311,958
	LIABILITIES HELD FOR SALE
	Operator Payable	486,088	126,947
	Eagle Ford asset purchase payable	190,000	190,000
	Due to the Caltex bankruptcy estate	123,202	123,202
	Current liabilities held for sale	799,290	440,149
	Due to the Caltex bankruptcy estate	834,054	771,717
	Asset retirement obligations	2,683,807	2,485,007
	Non-current liabilities held for sale	3,517,861	3,256,724
	Depletion expense for the year ended December 31, 2013 and 2012 was $26,408 and $24,377 respectively.
	Depreciation expense for the year ended December 31, 2013 and 2012 was $97,284 and $73,107, respectively.
	The Company determined at December 31, 2013 that due to its plan of sale and the subsequent consummation in February 2014, that the sale would significantly alter the relationship between capitalized costs and it’s proved reserves. The Company has thus included in its loss from operations an impairment charge at December 31, 2013 amounting to $10,607,064. The Company calculated the impairment as the difference between the carrying amount of its oil and gas properties as of December 31, 2013 and the carrying value of the salvage equipment and the value of the liabilities assumed by Eagle Ford. The Company valued the note receivable of $500,000 at zero fair value. The Company also did not include certain liabilities that the Company took over from Eagle Ford during 2013 as the third parties were not party to the transaction. The Company has treated those liabilities in which it agreed with the third party to become liable for as having a continuing guarantee to those third parties. In addition, the Company performed a recalculation of the value of its proved reserves under the 10% carried working interest it obtained in the sale. The Company valued those reserves at $1,571,000. The excess of the liabilities transferred to Eagle Ford against the value of the salvage equipment over and above the $1,571,000 in proved reserves was $1,862,117, which the Company has moved to unproved reserves as of December 31, 2013.

FURNITURE_FIXTURES_AND_EQUIPME

FURNITURE, FIXTURES AND EQUIPMENT	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment Disclosure [Text Block]	'
	NOTE 6 - FURNITURE, FIXTURES AND EQUIPMENT
	Furniture, fixtures and equipment consisted of the following as of December 31:
		2013		2012
	Office furniture and equipment	$	14,939	$	-
	Accumulated depreciation		-		-
		$	14,939	$	-

NOTES_AND_ADVANCES_PAYABLE

NOTES AND ADVANCES PAYABLE	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Debt Disclosure [Text Block]	'
	NOTE 7 - NOTES AND ADVANCES PAYABLE
	On December 22, 2012, the Company issued an unsecured promissory note in the amount of $200,000 to Michael J. Garnick, a stockholder. The promissory note accrued interest at 10% per annum and was due on February 15, 2012.  As a condition for issuing the promissory note, the Company was obligated to issue 90,000 shares of its common stock to Michael J. Garnick. The relative fair value of the 90,000 shares of $750 was recognized as a discount to the debt. The debt discount is accreted to interest expense over the term of the promissory note. The note was repaid in full in March 2012.
	In connection with the acquisition of Pan Am the Company acquired certain advances payable and short term bridge notes in the principal amount of $1,900,000 from two unaffiliated entities. Of the $1,900,000 borrowed, $600,000 was evidenced by an unsecured promissory note, had an interest rate of 10% per annum and was repaid March 2012. The remaining $1,300,000 borrowed was evidenced by a series of loan agreements all with essentially the same terms; interest at the rate of 6% per annum, unsecured, and due on the earlier of December 31, 2012 or upon demand. As of December 31, 2013, $350,000 was due on this loan. The Company is currently in negotiations with the lender to extend the maturity date of the loan.
	In addition, in 2011 Pan Am was advanced approximately $90,000 by a then related party. The advance is non-interest bearing, is unsecured and due on demand and as of December 31, 2013 the balance the Company owed is $90,704.
	On February 24, 2012, the Company received gross proceeds of $2.5 million from the sale of two promissory notes to two unrelated entities. The notes mature on December 31, 2014, bear interest at the rate of 8% per annum, are unsecured and are convertible into up to 2.5 million shares of the Company’s common stock, subject to certain adjustments, at the option of the holders. In addition, should the Company’s common stock trade above $2.50 for a period of 30 or more consecutive trading days, the notes and all accrued and unpaid interest automatically convert into common stock of the Company, at the conversion rate then in effect. The Company determined that at issuance, no beneficial conversion feature was present.
	In connection with the $2.5 million notes noted above, the Company paid a 10% fee to and unrelated third party who helped facilitate the transaction. The fee is being amortized on a straight line basis over the life of the loans. Through December 31, 2012 and December 31, 2013 the Company amortized approximately $73,529 and $115,988 to interest expense. At December 31, 2013, the balance the Company owed was $2.5 million.
	On April 30, 2012, the Company received gross proceeds of $750,000 from the sale of a promissory note that matures on April 30, 2017, is unsecured and bears interest at the rate of 3% per annum. The note contains conversion privileges such that the holder may convert at any time into common stock of the Company at a conversion rate of $0.75 per share. The conversion feature includes standard anti-dilution provisions. The Company recorded a discount of $150,000 as a result of the beneficial conversion feature, and amortized approximately $13,829 of the discount through December 31, 2012. No discount was amortized in 2013 as it was immaterial. The balance owed at December 31, 2013 was $750,000.
	On May 21, 2012, the Company received gross proceeds of $300,000 from the sale of a promissory note that originally matured on the earlier of December 31, 2012 or upon the Company raising $1,500,000 in debt or equity after the sale of the note, bears interest at the rate of 6% per annum and is unsecured. On December 24, 2012, the maturity date of the note was extended until March 31, 2013. In combination with the $750,000 note described above, the Company paid fees totaling $110,000 to acquire these loans. Since the original loans both had maturity dates of December 31, 2012, the entire fee was amortized to interest expense during 2012. The amount owed at December 31, 2013 was $300,000. The Company is attempting to negotiate an extension of the maturity date of this note.
	In October 2012 through December 2012 the Company received gross proceeds of $ 1,635,000 from the sale of promissory notes to two stockholders that mature on the earlier of December 31, 2013 or upon the Company raising $1,500,000 in debt or equity after the sale of the notes. The notes bear interest at the rate of 6% per annum and are unsecured. During 2013, the Company borrowed an additional $1,267,600 from the same two stockholders on essentially the same terms with maturity dates ranging from January 2014, through September 2014. The amount owed at December 31, 2013 was $2,902,600. The Company is attempting to negotiate an extension of the maturity date of these notes.
	On May 25, 2012 the Company issued a note as part of the purchase price to acquire the 80% interest in the Eagle Ford Oil Co., Inc. oil and gas leaseholds (see Note 4 and 6) in the amount of $225,000 that matured on December 31, 2013, was unsecured and bears interest at the rate 5% per annum. As of December 31, 2012 and December 31, 2013 the unpaid balance of the loan was $190,000.
	In January 2013, the Company and 0947388 BC Ltd. (“094”) entered into a letter of intent for 094 to farm into the Edwards formation assets acquired through its acquisition of Pan American Oil Company, LLC (see Note 2) and Numa Luling, LLC (see Note 4) and also the 80% interest in certain leasehold interests acquired from Eagle Ford Oil Co., Inc. (see Note 4). The Company and 094 were unable to successfully negotiate a farm-in by 094. At the time of entering the letter of intent, 094 paid a deposit of $300,000. That deposit remains outstanding as of December 31, 2013 and is included in short term notes payable.
	In March and April 2013, the Company received gross proceeds of $110,000 from an unrelated third party and issued promissory notes in the same amount. Those notes bear interest at the rate of 6% per annum, are unsecured and mature on the earlier of the one year anniversary of upon the Company obtaining $1.5 mm in financing.
	On August 1, 2013, the Company entered into a secured promissory note with HII Technologies for $290,000. The Company entered into the promissory note to forestall mechanics lien issues with the Company’s leaseholds. HII Technologies was a drilling supplier for Eagle Ford who because of its own financial stress, had been unable to timely pay its suppliers, including HII Technologies. The Company and Eagle Ford agreed to reduce the Company’s operator payable to Eagle Ford by the same amount of the promissory note. The loan agreement bears interest at the rate of 5% per annum and matures on or before July 31, 2014. The loan is secured by a lien on the Company leasehold interest in 204 acres in Caldwell County, Texas (see Note 6).

PREFERRED_STOCK

PREFERRED STOCK	12 Months Ended
	Dec. 31, 2013
Preferred Stock [Abstract]	'
Preferred Stock [Text Block]	'
	NOTE 8 - PREFERRED STOCK
	Series A
	In connection with the acquisition of Pan Am, the Company issued 5,500,000 shares of Series A preferred stock as partial consideration for the purchase. The Series A preferred stock had an initial issue price of $1 per share and accrues a dividend quarterly to each holder at the rate of 3% per annum based on the original issue price, payable quarterly in cash or in kind. Series A preferred holders are required to have received all dividends before any dividend on common stock may be issued. The Series A preferred ranks senior to common stock in the event of a liquidation or winding up of the Company. The Series A preferred may be converted in whole or in part at any time at the option of the holder at the rate of 1 common share for each Series A Preferred, subject to adjustments as defined in the Series A certificate of designation. In addition, should the common stock of the Company trade in any over the counter market above $1.75 per share for a period of at least 30 consecutive trading days, the Company have an initial public offering of any class of securities in which gross proceeds are in excess of $50 million or consummate a merger in which the existing Company shareholders obtain less than 50% of the voting control of the combined entity, then the Series A preferred will automatically convert into the number of shares of common stock as the then conversion rate indicates. In the event that holders elect not to convert their Series A preferred or no automatic conversion is triggered, on January 31, 2019, the Series A preferred will become mandatorily redeemable for cash at its original issue price plus any unpaid dividends accrued as of that date. On the date of issuance, the Company determined that no beneficial conversion feature was present. As of December 31, 2013 the Company accrued $309,375 of Series A dividends.
	In March 2012, the Company commenced a separate offering of up to 10 million shares of Series A preferred stock in a private placement. As of December 31, 2013, no funds had yet been raised under the offering.
	Series B
	In connection with the acquisition of Numa (see Note 4), the Company issued 3,250,000 shares of Series B preferred stock as partial consideration for the purchase. The Series B preferred stock had an initial issue (also liquidation price) of $1 per share. The Series B ranks junior to the Series A preferred stock in respect to the payment of dividends but senior to shares of common stock. The Series B is non-cumulative and dividends must be declared before they become payable by the Company. The Series B ranks pari-passu in respect to liquidation and all other matters to the Series A preferred stock. Each share of Series B preferred stock may be converted at any time by the holder into 1.33 shares of common stock. In the event that the Company’s common stock trades above $1.75 per share for 30 consecutive trading days, the Company closes on a qualified sale (as defined in the agreement) in which the consideration to be received is greater than $50 million, or the Company has an underwritten public offering with proceeds in excess of $50 million, the Series B preferred stock automatically converts into common stock at the rate of 1.33 common shares for each Series B share. The holders also have standard anti-dilution protections. On the date of issuance, the Company determined that no beneficial conversion feature was present.
	Series C
	The Board of Directors adopted a resolution on July 30, 2013 authorizing 12,000,000 shares of Series C convertible redeemable preferred stock with a par value of $.001. The original issuance price was $1.00 per share. The Series C Preferred Stock shall, with respect to dividend rights and rights upon liquidation, winding up or dissolution, rank junior to or pari passau to other classes or series of preferred stock and prior to common stock.
	The Corporation shall pay the holders of Series C Preferred Stock a dividend in an amount equal to five percent (5%) per annum multiplied by the Original Issue Price of the Series C Preferred Stock. Cumulative Preferred Dividends shall be payable in quarterly installments in cash or in kind, at the sole option of the Corporation.
	Each share of Series C Preferred Stock may be converted by any holder thereof, without any further consideration, at any time, into 1.11 shares of Common Stock (the “Conversion Rate”).
	Automatic Conversion. Each share of Series C Preferred Stock shall be automatically converted into shares of the Company’s Common Stock at the Conversion Rate upon the occurrence of any of the following events:
		(i)	The shares of the Corporation’s Common Stock shall trade at a price of over $1.75 per share (as adjusted for stock splits or other events which would result in an adjustment of the Conversion rate) for a period in excess of thirty (30) consecutive trading days and the shares of the Corporation’s Common Stock underlying the Series C Preferred Stock are either (i) included in an effective registration statement or (ii) eligible to be traded pursuant to an applicable exemption from registration.
		(ii)	The sale of all or substantially all of the assets of the Corporation or the outstanding shares of capital stock of the Corporation entitled to vote generally for the election of directors..
		(iii)	The merger of the Company which results in the shareholders of the Company prior to the merger owning less than fifty percent (50%) of the voting power of the Company following the merger.
		(iv)	An underwritten initial public offering of the Company’s shares with gross proceeds of at least $50,000,000.
	The conversion rate will be adjusted for the following:
		⋅	Stock Splits and Combinations.
		⋅	Certain Dividends and Distributions.
		⋅	Other Dividends and Distributions.
		⋅	Adjustments for Reclassification, Exchange or Substitution.
		⋅	Adjustments for Reorganization, Merger, Consolidation or Sales of Assets.
		⋅	Consideration for Stock. In case any shares of Common Stock or Convertible Securities other than the Series C Preferred Stock, or any rights or warrants or options to purchase any such Common Stock or Convertible Securities, shall be issued or sold in connection with a merger or consolidation.
	The Corporation shall mandatorily redeem all shares of Series C Preferred Stock which remain issued and outstanding at January 31, 2019 (“Redemption Date”) at a price equal to the sum of the Original Issue Price and the aggregate amount of any unpaid Cumulative Preferred Dividends attributable to such shares. Such redemption shall be made only to the extent the Corporation has funds legally available for such redemption as of the Redemption Date.
	Except as otherwise provided herein or required by law, the holders of the Series C Preferred Stock shall be entitled to vote together as a single class with the holders of Common Stock and any other capital stock of the Corporation entitled to vote, upon any matter submitted to the stockholders for a vote. The holders of Series C Preferred Stock shall be entitled to one vote for each share of Common Stock into which each share of Series C Preferred Stock held by such holders at the record date for the determination of the stockholders entitled to vote on such matters or, if no such record date is established, at the date such vote is taken, is convertible.
	During the quarter ending September 30, 2012 the Company raised gross proceeds of $492,000 and issued 492,000 shares of Series C preferred stock. In addition, the Company issued one warrant for each share of Series C preferred stock sold in the offering.  Each warrant entitles the holder to acquire one share of the Company’s common stock, at an exercise price of $2.50 per share and expires 3 years from the date of issuance.

COMMON_STOCK

COMMON STOCK	12 Months Ended
	Dec. 31, 2013
Common Stock [Abstract]	'
Common Stock Disclosure [Text Block]	'
	NOTE 9 - COMMON STOCK
	On December 16, 2011, the Company filed a Preliminary Information Statement on Schedule 14-C disclosing that the holder of a majority of the Company’s common stock voted to (i) approve an amendment to the Company’s Articles of Incorporation to (a) change the name of the Company from Soton Holdings Group, Inc. to “Rio Bravo Oil, Inc.”, (b) increase the authorized common stock from 75,000,000 shares, par value $0.001, to 120,000,000 shares, par value $0.001, and (c) create a class of preferred stock, consisting of 30,000,000 shares, par value $0.001, the rights, privileges, and preferences of which may be set by the Company’s Board of Directors without further shareholder approval; and (ii) grant the Board of Directors the authority to amend the Company’s Articles of Incorporation in the future for the purpose of effectuating a forward stock split at a ratio between 2-for-1 and 30-for-1 without further approval by the shareholders.  These actions were approved by the holder of a majority of the Company’s voting securities. The name change, increase in authorized common stock and authorized preferred stock took effect with the Secretary of State for the State of Nevada on January 19, 2012, with the name change to Rio Bravo Oil, Inc. recognized by FINRA and the OTC Bulletin Board effective January 26, 2013. The forward stock split became effective as of February 15, 2012. All share amounts have been restated for the forwards stock split since inception.
	Beginning in February 2012, in connection with the acquisition of Pan Am, the Company commenced a private placement offering of up to a maximum of 6,000,000 units, with each unit consisting of 1 share of common stock and 1 warrant to acquire 1 share of common stock of the Company, with an offering price of $0.75 per unit. The warrants have an exercise price of $1.50 per share and an exercise period of 3 years from the date of issuance. As part of the offering, the Company agreed to pay commissions of 10% of the gross funds raised. As of December 31, 2012, the Company had raised gross funds of approximately $2,656,250 and had accrued commission payable of approximately $265,000, included in accrued expenses. In addition, the Company had one signed private placement commitment of $500,000 for 666,666 units which was subsequently cancelled. In connection with the offering the Company incurred certain professional fee costs of approximately $41,000, which has been offset against the proceeds received in additional paid in capital.
	On March 28, 2012, the Company’s majority investor cancelled 66,500,000 shares of common stock in return for no consideration.
	In May 2012 the Board of Directors adopted a stock compensation plan. The plan allows the Company to issue shares of common stock, options to purchase common stock or stock appreciation rights to employees, directors and consultants employed by the Company. The number of shares of common stock issuable under the plan is determined each January 1, such that the plan may issue shares of common stock or instruments to acquire common stock of the Company up to 15% of the then outstanding common stock of the Company. No awards were granted or outstanding during the period ending December 31, 2012 and December 31, 2013.
	In July 2012, the Company issued 100,000 shares of its common stock as compensation for investor relations services. The stock was valued at its trading price of $0.86 per share on the date of the agreement.
	In January 2013, one holder of the Series A preferred stock converted 110,000 shares of Series A preferred stock into 110,000 shares of common stock of the Company.
	Warrants
	The Company issued a warrant to purchase 500,000 shares of the Company’s common stock to a consultant for services rendered in 2012. The exercise price of the warrant is $1.50 and expires in three years. The warrant was valued using a Black Scholes model based on a fair value of the stock of $.99 per share, a volatility of 28.20 and a risk free rate of .005%. The amount of the consulting expense recorded was $33,650.
	No warrants were issued in 2013.

INCOME_TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Tax Disclosure [Text Block]	'
	NOTE 10 – INCOME TAXES
	The provision for income taxes consists of the following for the years ended December 31:
		2013		2012
	Federal	$	-	$	-
	State and local		-		-
	Foreign		-		-
	Total income tax expense	$	-	$	-
		2013		2012
	Current	$	-	$	-
	Deferred		-		-
	Total Income Tax Expense	$	-	$	-
	For the year ended December 31, 2013 and the three months ended December 31, 2012, the provision for income taxes differs from the expected tax provision computed by applying the U.S. federal statutory rate to income before taxes as a result of the following:
		2013		2012
	Statutory U.S. federal rate	35	%	35	%
	Permanent differences	0	%	0	%
	Valuation allowance	35	%	35	%
	Provision for income tax expense (benefit)	0	%	0	%
	The significant components of the Company’s deferred tax assets and liabilities are as follows:
		2013		2012
	Deferred Tax Assets:
	Net Operating Loss Carryforwards	$	2,401,000	$	1,204,000
	Non-cash compensation		-		-
	Provision for fixed asset impairment		3,683,000		-
	Accrued Liabilities		-		-
	Total Deferred Tax Assets		6,084,000		1,204,000
	Deferred Tax Liabilities:
	Total Deferred Tax Liabilities		-		-
	Net Deferred Tax Asset		6,084,000		1,204,000
	Valuation Allowance		-6,084,000		-1,204,000
	Net Deferred Tax Asset	$	-	$	-
	At December 31, 2013 and 2012, the Company had net operating loss carry forwards for U.S. federal income tax of approximately $6,940,000 and $3,440,000, which will begin to expire in 2030.
	The Company continually assesses both positive and negative evidence to determine whether it is more likely than not that deferred tax assets can be realized prior to their expiration. Management monitors Company-specific, industry and worldwide economic factors and assesses the likelihood that the Company’s NOL’s and other deferred tax attributes in the United States, state and local tax jurisdictions will be utilized prior to their expiration. The Company establishes a valuation allowance to reduce any net deferred tax assets for which it is determined that it is more likely than not that some portion of the net deferred tax asset will not be realized. At December 31, 2013, the Company had a valuation allowance of $6.084 million related to its net deferred tax assets.
	For financial reporting purposes, the entire amount of deferred tax assets related principally to the net operating loss carry forwards has been offset by a valuation allowance due to uncertainty regarding the realization of the assets. The valuation allowance increased by approximately $4.88 million and $1.197 million for the years ended December 31, 2013 and 2012, respectively.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies Disclosure [Text Block]	'
	NOTE 11 - COMMITMENTS AND CONTINGENCIES
	General
	There have been significant changes in the U.S. economy, oil and gas prices and the finance industry which have adversely affected and may continue to adversely affect the Company in its attempt to obtain financing or in its process to produce commercially feasible gas exploration or production.
	Federal, state and local authorities regulate the oil and gas industry. In particular, gas and oil production operations and economies are affected by environmental protection statutes, tax statutes and other laws and regulations relating to the petroleum industry, as well as changes in such laws, changing administrative regulations and the interpretations and application of such laws, rules and regulations. The Company believes it is in compliance with all federal, state and local laws, regulations, and orders applicable to the Company and its properties and operations, the violation of which would have a material adverse effect on the Company or its financial condition.
	Operating Hazards and Insurance
	The gas and oil business involves a variety of operating risks, including the risk of fire, explosions, blow-outs, pipe failure, abnormally pressured formation, and environmental hazards such as oil spills, gas leaks, ruptures or discharges of toxic gases, the occurrence of any of which could result in substantial losses to the Company due to injury or loss of life, severe damage to or destruction of property, natural resources and equipment, pollution or other environmental damage, cleanup responsibilities, regulatory investigation and penalties, and suspension of operations.
	The Company is a passive working and net revenue interest owner and operator in the oil and gas industry. As such, the Company to date has not acquired its own insurance coverage over its passive interests in the properties; instead the Company has relied on the third party operators for its properties to maintain insurance to cover its operations.
	There can be no assurance that insurance, if any, will be adequate to cover any losses or exposure to liability. Although the Company believes the policies obtained by the third party operators provide coverage in scope and in amounts customary in the industry, they do not provide complete coverage against all operating risks. An uninsured or partially insured claim, if successful and of significant magnitude, could have a material adverse effect on the Company and its financial condition via its contractual liability to the prospect.
	Title to Properties
	The Company’s practice has been to acquire or have its members contribute ownership or leasehold rights to oil and natural gas properties from third parties. The Company’s existing rights are dependent on those previous third parties having obtained valid title to the properties. Prior to the commencement of oil or gas drilling operations on those properties, the third parties customarily conduct a title examination. The Company generally does not conduct examinations of title prior to obtaining its interests in its operations, but rely on representations from the third parties that they have good, valid and enforceable title to the oil and gas properties. Based upon the foregoing, the Company believes it has satisfactory title to their producing properties in accordance with customary practices in the oil and gas industry. The Company is not aware of any title deficiencies as of the date of these financial statements.
	Potential Loss of Oil and Gas Interests/Cash Calls
	The Company has agreed to be bound by the existing joint operating agreements with various operators for the drilling of oil and gas properties, and still owes certain operator payments on drilling wells. In addition, the Company might be subject to future cash calls due to (1) the drilling of any new well or wells on drilling sites; (2) rework or recompletion of a well; and (3) deepening or plugging back of dry holes, etc. If the Company does not pay delinquent amounts due or its share of future authorization for expenditures invoices, it may forfeit all of its rights in certain of its interests on the applicable prospects and any related profits. If one or more of the other members of the prospects fail to pay their share of the prospect costs, the Company may need to pay additional funds to protect its investments.

NON_CASH_DISCLOSURES_NOT_MADE_

NON CASH DISCLOSURES NOT MADE ELSEWHERE	12 Months Ended
	Dec. 31, 2013
Other Significant Noncash Transactions [Abstract]	'
Disclosure Of Other Significant Noncash Transactions [Text Block]	'
	NOTE 12 - NON CASH DISCLOSURES NOT MADE ELSEWHERE
	No amounts were paid for income taxes in the periods presented in these financial statements.
	In 2013 because of the cash flow difficulties of the operator of the Company’s oil and gas leaseholds, the Company agreed to take over a drilling payable of the operator and signed a note payable to HII Technologies, Inc. (the note is more fully described in Note 7) and the operator agreed to reduce the payable the Company owes to the operator by the same amount.

SUBSEQUENT_EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events [Text Block]	'
	NOTE 13 – SUBSEQUENT EVENTS
	In February 2014, the Company and Eagle Ford entered into an asset purchase agreement whereby the Company sold to Eagle Ford all of its interest in all of its oil and gas leaseholds. As consideration, the Company received a promissory note in the amount of $500,000 and Eagle Ford agreed to take over all of the associated liabilities of the Company in respect to those leaseholds. In addition, Eagle Ford conveyed to the Company an unencumbered 10% carried working interest in all of the leaseholds sold to Eagle Ford.
	During the first quarter of 2014, the Company received gross proceeds of $89,000 that was advanced by a shareholder of Company. In addition, an unrelated third party advanced the Company an additional $37,000.
	In March 2014, one Series A preferred shareholder converted 500,000 shares of Series A preferred stock into 550,000 shares of common stock of the Company.
	In March and April 2014, the CEO advanced the Company a total $11,000.

SUPPLEMENTAL_OIL_AND_GAS_DISCL

SUPPLEMENTAL OIL AND GAS DISCLOSURE (unaudited)	12 Months Ended
	Dec. 31, 2013
Oil and Gas Revenue [Abstract]	'
Oil and Gas Exploration and Production Industries Disclosures [Text Block]	'
	NOTE 14 - SUPPLEMENTAL OIL AND GAS DISCLOSURE (unaudited)
	ESTIMATED NET QUANTITIES OF OIL AND GAS RESERVES (unaudited)
	Users of this information should be aware that the process of estimating quantities of “proved” and “proved developed” natural gas and crude oil reserves is very complex, requiring significant subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors including, but not limited to, additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. Consequently, material revisions to existing reserve estimates occur from time to time. Although every reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the significance of the subjective decisions required and variances in available data for various reservoirs make these estimates generally less precise than other estimates presented in connection with financial statements.
	Proved oil and gas reserves are those quantities of natural gas, crude oil and condensate, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations prior to the time at which contacts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the Company must be reasonably certain that it will commence the project within a reasonable time.
	Proved developed reserves are proved reserves that can be expected to be recovered through existing wells with existing equipment and under existing economic and operating conditions.
	Oil and Gas Reserves
	The following tables set forth our net proved oil and gas reserves, including the changes therein, and net proved developed reserves at December 31, 2013 and 2012.
	Net proved Developed and Undeveloped Reserves (thousands of barrels “Mbbl”) of oil:
		2013		2012
		(unaudited)		(unaudited)
	1-Jan	1,175		-
	Purchase of properties	-		1,176
	Revisions of previous estimates	-925		-
	Extension, discoveries, other estimates	-		-
	Production	-1		-1
	Disposition of properties	-		-
	31-Dec	249		1,175
	Net proved oil reserves (in mbbl) consisted of the following at December 31:
		2013		2012
		(unaudited)		(unaudited)
	Proved developed not producing	249		249
	Proved undeveloped	-		926
	Total proven	249		1,175
	Results of operations for oil and gas producing activities for the year ended December 31:
		2013			2012
		(unaudited)			(unaudited)
	Revenue	$	120,153		$	101,556
	Operating expenses (lifting costs and workover expenses)		1,485,201			799,386
	Depletion and depreciation		26,408			24,377
	Impairment of oil and gas properties		10,607,064			-
	Operating loss		-11,998,520			-722,207
	Income tax provision (net of valuation allowance)		-			-
	Results of operations for oil and gas properties	$	-11,998,520		$	-722,207
	Cost incurred for oil and gas property acquisition, exploration and development for the periods ended December 31:
	Activities	2013			2012
		(unaudited)			(unaudited)
		(in thousands)			(in thousands)
	Property acquisition
	Unproved	$	-		$	-
	Proved		9			16,024
	Exploration		-			-
	Development		-			1,717
	Total costs incurred	$	9		$	17,741
	Capitalized costs relating to oil and gas activities are as follows:
		2013			2012
		(unaudited)			(unaudited)
		(in thousands)			(in thousands)
	Proved	$	15,888		$	17,741
	Unproved		1,862			-
	Total capitalized costs		17,750			17,741
	Accumulated depletion, depreciation and impairment		-10,884			-24
	Net capitalized costs	$	6,866		$	17,717
	STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS RELATING TO PROVED OIL AND GAS RESERVES — (unaudited)
	The following information has been developed utilizing procedures prescribed by FASC Topic 932 and based on crude oil reserve and production volumes estimated by the Company’s engineering staff. It may be useful for certain comparative purposes, but should not be solely relied upon in evaluating the Company or its performance. Further, information contained in the following table should not be considered as representative of realistic assessments of future cash flows, nor should the Standardized Measure of Discounted Future Net Cash Flows be viewed as representative of the current value of the Company.
	The Company believes that the following factors should be taken into account in reviewing the following information: (1) future costs and selling prices will probably differ from those required to be used in these calculations; (2) actual rates of production achieved in future years may vary significantly from the rate of production assumed in the calculations; (3) selection of a 10% discount rate is arbitrary and may not be reasonable as a measure of the relative risk inherent in realizing future net oil and gas revenues; and (4) future net revenues may be subject to different rates of income taxation.
	Under the Standardized Measure, future cash inflows were estimated by applying the average first day price for each month during the period adjusted for fixed and determinable escalations to the estimated future production of period-end proven reserves. Future cash inflows were reduced by estimated future development, abandonment and production costs based on period-end costs in order to arrive at net cash flow before tax. Future income tax expenses have been computed by applying period-end statutory tax rates to aggregate future pre-tax net cash flows, reduced by the tax basis of the properties involved and tax carryforwards. Use of a 10% discount rate is required by FASC Topic 932.
	Management does not rely solely upon the following information in making investment and operating decisions. Such decisions are based upon a wide range of factors, including estimates of probable as well as proven reserves and varying price and cost assumptions considered more representative of a range of possible economic conditions that may be anticipated.
	Standardized measure of discounted future net cash flows relating to proved oil and gas reserves.
	The standardized measure of discounted future net cash flows relating to proved oil and gas reserves for the Company is as follows for the periods ended December 31:
		2013			2012
		(in thousands)			(in thousands)
		(unaudited)			(unaudited)
	Future cash inflows	$	22,407		$	105,600
Less related future:
Production costs		-5,678			-18,098
Development costs		-2,625			-18,825
Future net cash flows before income taxes		14,104			68,677
Future income taxes		-			-24,037
Future net cash flows		14,104			44,640
10% annual discount for estimating timing of cash flows		-4,170			-14,496
Standardized measure of discounted future net cash flows	$	9,934		$	30,144
A summary of the changes in the standardized measure of discounted future net cash flows applicable to proved oil and gas reserves is as follows for the periods ended December 31:
	2013			2012
	(in thousands)			(in thousands)
	(unaudited)			(unaudited)
Net changes in sales and transfer prices and in production	$	-		$	-
(lifting) costs related to future production
Changes in estimated future development costs		-			-
Sales and transfers of oil and gas produced during the period		-122			-100
Net change due to extensions, discoveries and improved
recovery		-			30,244
Net change due to purchases and sales of minerals in place		-			-
Net change due to revisions in quantity estimates		-20,088			-
Previously estimated development costs incurred during the period		-			-
Accretion of discount		-			-
Other – unspecified		-			-
Net change in income taxes		-			-
Aggregate change in the standardized measure of discounted
net cash flows for the year	$	-20,210		$	30,144

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Consolidation, Policy [Policy Text Block]	'
	Principles of Consolidation
	The consolidated financial statements included herewith include the accounts of the Company and its wholly-owned subsidiary. All significant inter-company balances and transactions have been eliminated in consolidation.
Cash and Cash Equivalents, Policy [Policy Text Block]	'
	Cash and cash equivalents
	The Company considers all highly liquid instruments with original maturity of less than 90 days to be cash equivalents.
Exploration Stage Enterprise Policy [Policy Text Block]	'
	Exploration Stage Enterprise
	The Company has been devoting most of its efforts to exploring for and developing its oil and gas assets and, consequently, meets the definition of An Exploration Stage Enterprise, under the Accounting Standards Codification “Accounting and Reporting for Development Stage Enterprises.” Certain additional financial information is required to be included in the financial statements for the period from inception of the Company to the current balance sheet date.
Property, Plant and Equipment, Policy [Policy Text Block]	'
	Furniture, Fixtures & Equipment
	Property and equipment are stated at cost less accumulated depreciation and are depreciated using the straight-line method over the assets’ estimated useful lives. Principal useful lives are as follows:
	Oil field equipment	7 years
	Normal maintenance and repairs for property and equipment are charged to expense as incurred, while significant improvements are capitalized.
	In accordance with authoritative guidance on accounting for the impairment or disposal of long-lived assets, as set forth in Topic 360 of the Financial Accounting Standards Board Accounting Standards CodificationTM (the “FASC”), the Company assesses the recoverability of the carrying value of its non-oil and gas long-lived assets when events occur that indicate an impairment in value may exist. An impairment loss is indicated if the sum of the expected undiscounted future net cash flows is less than the carrying amount of the assets. If this occurs, an impairment loss is recognized for the amount by which the carrying amount of the assets exceeds the estimated fair value of the asset.
Oil and Gas Properties Policy [Policy Text Block]	'
	Oil and Gas Properties
	The Company follows the full cost method of accounting for oil and natural gas operations. Under this method all productive and nonproductive costs incurred in connection with the acquisition, exploration, and development of oil and natural gas reserves are capitalized on a country-by-country basis into an individual country “cost pool.” The Company has operations in the United States and, consequently, only has one cost pool. No gains or losses are recognized upon the sale or other disposition of oil and natural gas properties except in transactions that would significantly alter the relationship between capitalized costs and proved reserves. The costs of unevaluated oil and natural gas properties are excluded from the amortizable base until the time that either proven reserves are found or it has been determined that such properties are impaired. As properties become evaluated, the related costs are transferred to the proved oil and natural gas properties cost pool using full cost accounting.
	Under the full cost method the net book value of oil and natural gas properties, less related deferred income taxes, may not exceed the estimated after-tax future net revenues from proved oil and natural gas properties, discounted at 10% (the “Ceiling Limitation”). In arriving at estimated future net revenues, estimated lease operating expenses, development costs, and certain production-related and ad valorem taxes are deducted. In calculating future net revenues, prices and costs are held constant indefinitely, except for changes that are fixed and determinable by existing contracts. Prices are determined using a simple arithmetic average of the first day of each month during the most recent twelve month period presented herein. The net book value is compared to the Ceiling Limitation on a quarterly and yearly basis. The excess, if any, of the net book value above the Ceiling Limitation is charged to expense in the period in which it occurs and is not subsequently reinstated.
	Unit-of-production depletion is applied to capitalized costs of the full cost pool. Unit-of-production rates are based on the amount of proved reserves (both developed and undeveloped) of oil, gas and other minerals that are estimated to be recoverable from existing facilities using current operating methods.
	The costs of investments in unproved properties and portions of costs associated with major development projects are excluded from the depreciation, depletion and amortization calculation until the project is evaluated.
	Unproved property costs include leasehold costs, seismic costs and other costs incurred during the exploration phase. In areas where proved reserves are established, significant unproved properties are evaluated periodically, but not less than annually, for impairment. If a reduction in value has occurred, these property costs are considered impaired and are transferred to the related full cost pool. Unproved properties whose acquisition costs are not individually significant are aggregated, and the portion of such costs estimated to be ultimately nonproductive, based on experience, and is amortized to the full cost pool over an average holding period.
Use of Estimates, Policy [Policy Text Block]	'
	Use of Estimates
	The preparation of the Company’s financial statements in accordance with US GAAP 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. Management believes that the following material estimates affecting the financial statements could significantly change in the coming year.
	The most significant estimates pertain to proven oil and natural gas reserves and related cash flow estimates used in impairment tests of long-lived assets, estimates of future development, dismantlement and abandonment costs. Certain of these estimates require assumptions regarding future costs and expenses and future production rates. Actual results could differ from those estimates.
	The Company’s revenue, profitability and future growth are substantially dependent upon the prevailing and future prices for oil and natural gas, which are dependent upon numerous factors beyond their control such as economic, political and regulatory developments and competition from other energy sources. The energy markets have historically been very volatile and there can be no assurance that oil and natural gas prices will not be subject to wide fluctuations in the future. A substantial or extended decline in oil and natural gas prices could have a material adverse effect on the Company’s financial position, results of operations, cash flows and quantities of oil and natural gas reserves that may be economically produced.
	Estimates of oil and natural gas reserves and their values, future production rates and future costs and expenses are inherently uncertain for numerous reasons, including many factors beyond the Company’s control. Reservoir engineering is a subjective process of estimating underground accumulations of oil and natural gas that cannot be measured in an exact manner. The accuracy of any reserve estimate is a function of the quality of data available and of engineering and geological interpretation and judgment. In addition, estimates of reserves may be revised based on actual production, results of subsequent exploration and development activities, prevailing commodity prices, operating cost and other factors. These revisions may be material and could materially affect future depletion, depreciation and amortization expense, dismantlement and abandonment costs, and impairment expense.
Revenue Recognition, Policy [Policy Text Block]	'
	Revenue Recognition
	Revenues are recognized when hydrocarbons have been delivered, the customer has taken title and payment is reasonably assured.
Taxes Associated With Revenue Producing Transactions [Policy Text Block]	'
	Taxes Associated with Revenue Producing Transactions
	The Company reports taxes assessed by state, local and U.S. federal governmental authorities from the production and sale of hydrocarbons on a line item under operating expenses.
Income Tax, Policy [Policy Text Block]	'
	Income Taxes
	Income taxes are provided for the tax effects of transactions reported in the financial statements and consist of taxes currently due plus deferred taxes related primarily to differences between the bases of certain assets and liabilities for financial and tax reporting. The deferred taxes represent the future tax return consequences of those differences, which will either be deductible or taxable when the assets and liabilities are recovered or settled. Valuation allowances are provided against deferred tax assets if it is more likely than not that the deferred asset will not be realized.
	The Company follows the guidance of FASC 740 Income Taxes, Accounting for Uncertainty in Income Taxes, which prescribes a comprehensive model for how a company should measure, recognize, present, and disclose in its financial statements uncertain tax positions that the company has taken or expects to take on income tax returns.
	The Company recognizes the tax benefits from uncertain tax positions only if it is more likely than not that the tax position will be sustained on examination. The tax benefits recognized in the financial statements from such positions are measured based on the largest benefit that has a greater than 50% likelihood of being realized upon ultimate settlement. As of December 31, 2013 and 2012, the Company has not taken any uncertain tax positions.
Asset Retirement Obligations, Policy [Policy Text Block]	'
	Asset Retirement Obligations
	The Company provides for future asset retirement obligations on its resource properties and facilities based on estimates established by current legislation and industry practices. The asset retirement obligation is initially measured at fair value and capitalized as an asset retirement cost that is amortized on a straight line 15 year basis. The obligation is accreted through interest expense until it is expensed and or settled. The fair value of the obligation is estimated based on recent operations in the area and is then accreted using an expected inflation rate for oil field service costs. The Company recognizes revisions to either the timing or amount of the original estimate as increases or decreases to the asset retirement obligation.
	The significant assumptions used to develop the expected liability during the period are as follows:
	Average cost to remediate individual well sites: $4,000 to $7,000 (net to our interest)
	Average gross salvage value expected from individual well sites remediated: $0 (net)
	Expected inflation rate for oil field service costs: 5%
	Risk weighted cost of credit: 8%
	Average time to abandonment: 20 years
	Actual retirement costs will be recorded against the obligation when incurred. Any difference between the recorded asset retirement obligation and the actual retirement costs incurred is recorded as a gain or loss in the settlement period.
Concentrations Risk [Policy Text Block]	'
	Concentrations
	Upon acquisition of oil and gas field interests, the Company also became a party to joint operating agreements (“JOA’s”) that define the rights and responsibilities third party operators and passive interest holders. Under the JOA, the third party operator is responsible for acquiring customers to sell the oil and gas produced and to either performing or contracting out to other third parties to perform services necessary to continue and maintain undeveloped acreage. Currently all of the Company’s leasehold interests have as their third party operator Eagle Ford Oil Co. Inc. which is controlled by the former managing member of both Pan Am Oil Co., LLC and Rio Bravo Oil, LLC.
Concentrations Of Market Risk [Policy Text Block]	'
	Concentrations of Market Risk
	The future results of the company’s oil and natural gas operations will be affected by the market prices of oil and natural gas. The availability of a ready market for oil and natural gas products in the future will depend on numerous factors beyond the control of the Company, including weather, imports, marketing of competitive fuels, proximity and capacity of oil and natural gas pipelines and other transportation facilities, any oversupply or undersupply of oil, natural gas and liquid products, the regulatory environment, the economic environment, and other regional and political events, none of which can be predicted with certainty.
	The Company operates in the exploration, development and production sector of the oil and gas industry. While certain of these customers and joint venture partners are affected by periodic downturns in the economy in general or in their specific segment of the oil and natural gas industry, the Company believes that its level of credit-related losses due to such economic fluctuations has been and will continue to be immaterial to the Company’s results of operations over the long-term.
Concentration Risk, Credit Risk, Policy [Policy Text Block]	'
	Concentrations of Credit Risk
	Financial instruments that potentially subject the Company to significant concentrations of credit risk consist primarily of cash. During the year the amount of bank deposits that exceeded Federal Deposit Insurance Corporation (“FDIC”) insurance can be material.
Fair Value Measurement, Policy [Policy Text Block]	'
	Fair Value
	As defined in authoritative guidance, 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 at the measurement date (“exit price”). To estimate fair value, the Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable.
	The authoritative guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities ("Level 1" measurements) and the lowest priority to unobservable inputs ("Level 3" measurements). The three levels of the fair value hierarchy are as follows:
	Level 1 - Observable inputs such as quoted prices in active markets at the measurement date for identical, unrestricted assets or liabilities.
	Level 2 - Other inputs that are observable, directly or indirectly, such as quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability.
	Level 3 - Unobservable inputs for which there is little or no market data and which the Company makes its own assumptions about how market participants would price the assets and liabilities.
	In instances in which multiple levels of inputs are used to measure fair value, hierarchy classification is based on the lowest level input that is significant to the fair value measurement in its entirety. The Company's assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment, and considers factors specific to the asset or liability.
Earnings Per Share, Policy [Policy Text Block]	'
	Net Loss Per Share
	Basic loss per share is calculated based on the weighted-average number of outstanding common shares. Diluted loss per share is calculated based on the weighted-average number of outstanding common shares plus the effect of dilutive potential common shares, using the treasury stock method. The Company’s calculation of diluted net loss per share excludes potential common shares as of December 31, 2013 and 2012 as the effect would be anti-dilutive (i.e. would reduce the loss per share). At December 31, 2013, warrants and preferred stock that were convertible into 12,639,453 shares of common stock were not included in the net loss per share calculation.
	In accordance with SEC Accounting Series Release 280, the Company computes its income or loss applicable to common stock holders by subtracting dividends on preferred stock, including undeclared or unpaid dividends if cumulative, from it reported net loss and reports the same on the face of its statement of operations.
New Accounting Pronouncements, Policy [Policy Text Block]	'
	Recent Accounting Pronouncements
	In the first quarter of 2013, the Company adopted guidance issued by the Financial Accounting Standards Board (the “FASB”) that simplifies how an entity tests indefinite-lived intangibles for impairment. The amended guidance allows companies to first assess qualitative factors to determine whether it is more-likely-than-not that an indefinite-lived intangible asset is impaired as a basis for determining whether it is necessary to perform the quantitative impairment test. The adoption of this guidance had no impact on the Company’s financial position and results of operations.
	During the fiscal first quarter of 2013, the Company adopted the FASB guidance related to additional reporting and disclosure of amounts reclassified out of accumulated other comprehensive income (AOCI). Under this new guidance, companies are required to disclose the effect of significant reclassifications out of AOCI on the respective line items on the income statement if the amount being reclassified is required under U.S. generally accepted accounting principles (GAAP) to be reclassified in its entirety to net income. For other amounts that are not required under GAAP to be reclassified in their entirety to net income in the same reporting period, an entity is required to cross-reference other disclosures required under GAAP that provide additional details about those amounts. This update became effective for annual and interim reporting periods for fiscal years beginning after December 15, 2012. The adoption of this guidance had no impact on the Company’s financial position and results of operations.

MERGER_WITH_PAN_AMERICAN_OIL_C1

MERGER WITH PAN AMERICAN OIL COMPANY, LLC (Tables)	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Schedule Of Purchase Price Allocations [Table Text Block]	'
	In connection with the merger, the consideration paid, and the assets acquired and liabilities assumed, recorded at fair value on the date of acquisition, are summarized in the following tables:
		In thousands
	Net assets acquired
	Cash	$	50
	Prepaids		22
	Proved oil and gas property		7,370
	Furniture, fixtures and equipment		292
	Other receivables		948
		$	8,682
	Liabilities
	Accounts payable & accrued expenses	$	415
	Loans payable		87
	Bridge notes payable		1,900
	Other liabilities		770
	Asset retirement obligations		10
		$	3,182
	Net identifiable assets/consideration paid	$	5,500
Business Acquisition, Pro Forma Information [Table Text Block]	'
	The unaudited pro forma information presented below is based on various assumptions and presented for comparative purposes only and is not necessarily indicative of the results of operations that actually would have been achieved if the acquisition had taken place at the beginning of 2012.
	Pro forma net sales	$	101,556
	Pro forma net loss to common stockholders	$	-3,765,764
	Pro forma basic and diluted loss per share	$	-0.08

ACQUISITION_OF_LEASEHOLD_INTER1

ACQUISITION OF LEASEHOLD INTERESTS FROM NUMA LULING, LLC AND EAGLE FORD OIL CO, INC. (Tables)	12 Months Ended
	Dec. 31, 2013
Acquisition Of Leasehold Interests [Abstract]	'
Schedule Of Purchase Price Allocations Acquisitions [Table Text Block]	'
	In connection with the merger, the consideration paid, and the assets acquired and liabilities assumed, recorded at fair value on the date of acquisition, are summarized in the following tables:
		In thousands
	Net assets acquired
	Cash	$	-
	Prepaids		182
	Proved oil and gas property		8,500
	Furniture, fixtures and equipment		376
		$	9,058
	Liabilities
	Accounts payable and accrued expenses	$	-
	Loans payable		295
	Other liabilities		727
	Asset retirement obligations		2,345
		$	3,367
	Net identifiable assets/consideration paid	$	5,691
Business Acquisition, Pro Forma Information Acquisition [Table Text Block]	'
	The unaudited pro forma information presented below is based on various assumptions and presented for comparative purposes only and is not necessarily indicative of the results of operations that actually would have been achieved if the acquisition had taken place at the beginning of 2012.
	Pro forma net sales	$	-
	Pro forma net loss to common stockholders	$	-3,772,266
	Pro forma basic and diluted loss per share	$	-0.08

DISPOSITION_AND_IMPAIRMENT_OF_1

DISPOSITION AND IMPAIRMENT OF OIL AND GAS INTERESTS (Tables)	12 Months Ended
	Dec. 31, 2013
Disposition And Impairment Of Oil And Gas Interests [Abstract]	'
Schedule of Assets And Liabilities Held For Sale [Table Text Block]	'
	The following table shows the assets and liabilities held for sale as of December 31:
		2013	2012
	ASSETS HELD FOR SALE
	Proved oil and gas property	15,888,126	17,741,096
	Unproved oil and gas property	1,862,117	-
	Accumulated depletion and impairment	-10,657,849	-24,377
	Net oil and gas properties	7,092,394	17,716,719
	Well Equipment	668,349	668,346
	Accumulated depreciation	-170,391	-73,107
	Net property, plant and equipment	497,958	595,239
	Total assets held for sale	7,590,352	18,311,958
	LIABILITIES HELD FOR SALE
	Operator Payable	486,088	126,947
	Eagle Ford asset purchase payable	190,000	190,000
	Due to the Caltex bankruptcy estate	123,202	123,202
	Current liabilities held for sale	799,290	440,149
	Due to the Caltex bankruptcy estate	834,054	771,717
	Asset retirement obligations	2,683,807	2,485,007
	Non-current liabilities held for sale	3,517,861	3,256,724

FURNITURE_FIXTURES_AND_EQUIPME1

FURNITURE, FIXTURES AND EQUIPMENT (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment [Table Text Block]	'
	Furniture, fixtures and equipment consisted of the following as of December 31:
		2013		2012
	Office furniture and equipment	$	14,939	$	-
	Accumulated depreciation		-		-
		$	14,939	$	-

INCOME_TAXES_Tables

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	'
	The provision for income taxes consists of the following for the years ended December 31:
		2013		2012
	Federal	$	-	$	-
	State and local		-		-
	Foreign		-		-
	Total income tax expense	$	-	$	-
		2013		2012
	Current	$	-	$	-
	Deferred		-		-
	Total Income Tax Expense	$	-	$	-
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	'
	For the year ended December 31, 2013 and the three months ended December 31, 2012, the provision for income taxes differs from the expected tax provision computed by applying the U.S. federal statutory rate to income before taxes as a result of the following:
		2013		2012
	Statutory U.S. federal rate	35	%	35	%
	Permanent differences	0	%	0	%
	Valuation allowance	35	%	35	%
	Provision for income tax expense (benefit)	0	%	0	%
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	'
	The significant components of the Company’s deferred tax assets and liabilities are as follows:
		2013		2012
	Deferred Tax Assets:
	Net Operating Loss Carryforwards	$	2,401,000	$	1,204,000
	Non-cash compensation		-		-
	Provision for fixed asset impairment		3,683,000		-
	Accrued Liabilities		-		-
	Total Deferred Tax Assets		6,084,000		1,204,000
	Deferred Tax Liabilities:
	Total Deferred Tax Liabilities		-		-
	Net Deferred Tax Asset		6,084,000		1,204,000
	Valuation Allowance		-6,084,000		-1,204,000
	Net Deferred Tax Asset	$	-	$	-

SUPPLEMENTAL_OIL_AND_GAS_DISCL1

SUPPLEMENTAL OIL AND GAS DISCLOSURE (unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Oil and Gas Revenue [Abstract]	'
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]	'
	Net proved Developed and Undeveloped Reserves (thousands of barrels “Mbbl”) of oil:
		2013		2012
		(unaudited)		(unaudited)
	1-Jan	1,175		-
	Purchase of properties	-		1,176
	Revisions of previous estimates	-925		-
	Extension, discoveries, other estimates	-		-
	Production	-1		-1
	Disposition of properties	-		-
	31-Dec	249		1,175
Schedule Of Proved Developed and Undeveloped Oil and Gas Reserve Volumes [Table Text Block]	'
	Net proved oil reserves (in mbbl) consisted of the following at December 31:
		2013		2012
		(unaudited)		(unaudited)
	Proved developed not producing	249		249
	Proved undeveloped	-		926
	Total proven	249		1,175
Results of Operations for Oil and Gas Producing Activities Disclosure [Table Text Block]	'
	Results of operations for oil and gas producing activities for the year ended December 31:
		2013			2012
		(unaudited)			(unaudited)
	Revenue	$	120,153		$	101,556
	Operating expenses (lifting costs and workover expenses)		1,485,201			799,386
	Depletion and depreciation		26,408			24,377
	Impairment of oil and gas properties		10,607,064			-
	Operating loss		-11,998,520			-722,207
	Income tax provision (net of valuation allowance)		-			-
	Results of operations for oil and gas properties	$	-11,998,520		$	-722,207
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]	'
	Cost incurred for oil and gas property acquisition, exploration and development for the periods ended December 31:
	Activities	2013			2012
		(unaudited)			(unaudited)
		(in thousands)			(in thousands)
	Property acquisition
	Unproved	$	-		$	-
	Proved		9			16,024
	Exploration		-			-
	Development		-			1,717
	Total costs incurred	$	9		$	17,741
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	'
	Capitalized costs relating to oil and gas activities are as follows:
		2013			2012
		(unaudited)			(unaudited)
		(in thousands)			(in thousands)
	Proved	$	15,888		$	17,741
	Unproved		1,862			-
	Total capitalized costs		17,750			17,741
	Accumulated depletion, depreciation and impairment		-10,884			-24
	Net capitalized costs	$	6,866		$	17,717
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]	'
	The standardized measure of discounted future net cash flows relating to proved oil and gas reserves for the Company is as follows for the periods ended December 31:
		2013			2012
		(in thousands)			(in thousands)
		(unaudited)			(unaudited)
	Future cash inflows	$	22,407		$	105,600
	Less related future:
	Production costs		-5,678			-18,098
	Development costs		-2,625			-18,825
	Future net cash flows before income taxes		14,104			68,677
	Future income taxes		-			-24,037
	Future net cash flows		14,104			44,640
	10% annual discount for estimating timing of cash flows		-4,170			-14,496
	Standardized measure of discounted future net cash flows	$	9,934		$	30,144
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]	'
	A summary of the changes in the standardized measure of discounted future net cash flows applicable to proved oil and gas reserves is as follows for the periods ended December 31:
		2013			2012
		(in thousands)			(in thousands)
		(unaudited)			(unaudited)
	Net changes in sales and transfer prices and in production	$	-		$	-
	(lifting) costs related to future production
	Changes in estimated future development costs		-			-
	Sales and transfers of oil and gas produced during the period		-122			-100
	Net change due to extensions, discoveries and improved
	recovery		-			30,244
	Net change due to purchases and sales of minerals in place		-			-
	Net change due to revisions in quantity estimates		-20,088			-
	Previously estimated development costs incurred during the period		-			-
	Accretion of discount		-			-
	Other – unspecified		-			-
	Net change in income taxes		-			-
	Aggregate change in the standardized measure of discounted
	net cash flows for the year	$	-20,210		$	30,144

BASIS_OF_PRESENTATION_AND_GOIN1

BASIS OF PRESENTATION AND GOING CONCERN (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Basis of Presentation [Line Items]	'	'
Stockholders deficit accumulated in the exploratory stage	($17,957,915)	($3,665,754)
Working Capital Deficit	$9,450,000	'

MERGER_WITH_PAN_AMERICAN_OIL_C2

MERGER WITH PAN AMERICAN OIL COMPANY, LLC (Details) (American Oil Company Llc [Member], USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
American Oil Company Llc [Member]	'
Net assets acquired	'
Cash	$50
Prepaids	22
Proved oil and gas property	7,370
Furniture, fixtures and equipment	292
Other receivables	948
Total Assets acquired	8,682
Liabilities	'
Accounts payable & accrued expenses	415
Loans payable	87
Bridge notes payable	1,900
Other liabilities	770
Asset retirement obligations	10
Total Liabilities	3,182
Net identifiable assets/consideration paid	$5,500

MERGER_WITH_PAN_AMERICAN_OIL_C3

MERGER WITH PAN AMERICAN OIL COMPANY, LLC (Details 1) (American Oil Company Llc [Member], USD $)	12 Months Ended
	Dec. 31, 2013
American Oil Company Llc [Member]	'
Business Acquisition [Line Items]	'
Pro forma net sales	$101,556
Pro forma net loss to common stockholders	($3,765,764)
Pro forma basic and diluted loss per share	($0.08)

MERGER_WITH_PAN_AMERICAN_OIL_C4

MERGER WITH PAN AMERICAN OIL COMPANY, LLC (Details Textual) (USD $)	12 Months Ended		43 Months Ended		12 Months Ended				0 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Jun. 30, 2012	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Feb. 14, 2012	Feb. 14, 2012
					Edwards Formation Leasehold [Member]	American Oil Company Llc [Member]	Series Preferred Stock [Member]	Series Preferred Stock [Member]	Pan American Oil Company, Llc [Member]	Pan American Oil Company, Llc [Member]
										Series Preferred Stock [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'	'
Stock Issued During Period, Shares, Acquisitions	'	'	'	'	'	'	5,500,000	'	'	5,500,000
Stock Issued During Period, Value, Acquisitions	'	$3,466,667	'	'	'	'	'	'	'	$500,000
Working Capital Interest In Oil and Gas Properties Before Pay Out	'	'	'	'	'	'	'	'	63.50%	'
Working Capital Interest In Oil and Gas Properties After Pay Out	'	'	'	'	'	'	'	'	57.00%	'
Sales Revenue Goods Net Percentage	'	'	'	'	'	'	'	'	38.00%	'
Business Acquisition Cost Of Acquired Entity Liabilities Incurred	'	'	'	'	364,000	'	'	'	120,000	'
Business Acquisition, Cost Of Acquired Entity, Cash Paid	'	'	'	'	'	'	'	113,000	966,000	'
Net identifiable assets consideration paid	'	'	'	'	'	'	'	'	1,600,000	'
Increase (Decrease) In Prepaid Expense	-26,196	2,158	-23,186	'	'	150,000	'	'	'	'
Increase (Decrease) In Accounts Payable	$869,296	($271,409)	$597,887	'	'	$150,000	'	'	'	'
Ownership Interest In Oil and Gas Properties Gross	'	'	'	4,500	'	'	'	'	4,500	'
Ownership Interest In Oil and Gas Properties Net	'	'	'	2,143	'	'	'	'	2,143	'

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Line Items]	'
Discount Rate	10.00%
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount (in shares)	12,639,453
Income Tax Benefit Description	'The tax benefits recognized in the financial statements from such positions are measured based on the largest benefit that has a greater than 50% likelihood of being realized upon ultimate settlement.
Oil Field Equipment [Member]	'
Accounting Policies [Line Items]	'
Property, Plant and Equipment, Useful Life	'7 years
Oil and Gas Properties [Member]	'
Accounting Policies [Line Items]	'
Asset Retirement Obligation Amortization Expected Term	'15 years
Property, Plant, and Equipment, Salvage Value	0
Fair Value Assumptions, Expected Volatility Rate	5.00%
Fair Value Assumptions, Risk Free Interest Rate	8.00%
Fair Value Assumptions, Expected Term	'20 years
Oil and Gas Properties [Member] | Minimum [Member]	'
Accounting Policies [Line Items]	'
Asset Retirement Obligation, Current	4,000
Oil and Gas Properties [Member] | Maximum [Member]	'
Accounting Policies [Line Items]	'
Asset Retirement Obligation, Current	7,000

ACQUISITION_OF_LEASEHOLD_INTER2

ACQUISITION OF LEASEHOLD INTERESTS FROM NUMA LULING, LLC AND EAGLE FORD OIL CO, INC. (Details) (Numa Luling Llc and Eagle Ford Oil Co Inc [Member], USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Numa Luling Llc and Eagle Ford Oil Co Inc [Member]	'
Net assets acquired	'
Cash	$0
Prepaids	182
Proved oil and gas property	8,500
Furniture, fixtures and equipment	376
Net assets Acquired,Total	9,058
Liabilities	'
Accounts payable and accrued expenses	0
Loans payable	295
Other liabilities	727
Asset retirement obligations	2,345
Liabilities,Total	3,367
Net identifiable assets/consideration paid	$5,691

ACQUISITION_OF_LEASEHOLD_INTER3

ACQUISITION OF LEASEHOLD INTERESTS FROM NUMA LULING, LLC AND EAGLE FORD OIL CO, INC (Details 1) (Numa Luling Llc and Eagle Ford Oil Co Inc [Member], USD $)	12 Months Ended
	Dec. 31, 2013
Numa Luling Llc and Eagle Ford Oil Co Inc [Member]	'
Acquisition Of Leasehold Interests [Line Items]	'
Pro forma net sales	$0
Pro forma net loss to common stockholders	($3,772,266)
Pro forma basic and diluted loss per share	($0.08)

ACQUISITION_OF_LEASEHOLD_INTER4

ACQUISITION OF LEASEHOLD INTERESTS FROM NUMA LULING, LLC AND EAGLE FORD OIL CO, INC. (Details Textual) (USD $)

12 Months Ended

43 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Aug. 01, 2013

Apr. 30, 2013

Jun. 30, 2012

Jun. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

31-May-12

Dec. 31, 2013

Sep. 30, 2013

25-May-12

Jun. 30, 2012

Dec. 31, 2013

Series B Preferred Stock [Member]

Series B Preferred Stock [Member]

Series B Preferred Stock [Member]

Eagle Ford Oil Co Inc [Member]

Eagle Ford Oil Co Inc [Member]

Eagle Ford Oil Co Inc [Member]

Eagle Ford Oil Co Inc [Member]

Numa Luling Llc [Member]

Numa Luling Llc and Eagle Ford Oil Co Inc [Member]

Acquisition Of Leasehold Interests [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period, Shares, Acquisitions

'

'

'

'

'

'

3,250,000

3,250,000

3,250,000

'

'

'

'

'

'

Ownership Interest In Oil and Gas Properties Gross

'

'

'

'

'

4,500

'

'

'

'

'

'

'

'

'

Ownership Interest In Oil and Gas Properties Net

'

'

'

'

'

2,143

'

'

'

'

'

'

'

'

'

Working Interest Acquired

80.00%

'

80.00%

'

'

'

'

'

'

80.00%

'

100.00%

'

25.00%

'

Net Revenue Interest Acquired

60.00%

'

60.00%

'

'

'

'

'

'

80.00%

'

'

'

18.75%

'

Productive Oil Wells, Number of Wells, Net

'

'

'

'

'

'

'

'

'

500

'

'

'

'

'

Business Acquisition, Cost Of Acquired Entity, Cash Paid

'

'

'

'

'

'

'

'

'

$2,000,000

'

'

'

'

'

Business Combination, Consideration Transferred, Liabilities Incurred

'

'

'

'

'

'

'

'

'

906,000

726,921

'

'

'

'

Business Acquisition Cost Acquired Entity Other Noncash Consideration

'

'

'

'

'

'

'

'

'

225,000

'

'

'

'

'

Due to CalTex Bankruptcy Estate

123,202

123,202

123,202

'

'

'

'

'

'

5,000

'

'

'

'

'

Development Wells Drilled, Net Productive

'

'

'

'

'

'

'

'

'

200

'

'

'

'

'

Option B Liability

'

'

'

'

'

'

'

'

'

1,000,000

'

'

'

'

'

Business Acquisition Purchase Price Allocation Liabilities Amount Assumed

'

'

'

'

'

'

'

'

'

295,000

'

'

'

'

'

Repayments of Debt

'

'

'

'

'

'

'

'

'

171,798

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

5.00%

6.00%

'

'

'

'

'

8.00%

'

5.00%

'

'

Stock Issued During Period, Value, Other

'

'

'

'

'

'

3,466,667

'

'

'

'

'

'

'

'

Increase Decrease In Proved Oil And Gas Property

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17,000

Increase (Decrease) In Prepaid Expense

($26,196)

$2,158

($23,186)

'

'

'

'

'

'

'

'

'

'

'

$17,000

DISPOSITION_AND_IMPAIRMENT_OF_2

DISPOSITION AND IMPAIRMENT OF OIL AND GAS INTERESTS (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
ASSETS HELD FOR SALE	'	'
Proved oil and gas property	$15,888,126	$17,741,096
Unproved oil and gas property	1,862,117	0
Accumulated depletion and impairment	-10,657,849	-24,377
Net oil and gas properties	7,092,394	17,716,719
Well Equipment	668,349	668,346
Accumulated depreciation	-170,391	-73,107
Net property, plant and equipment	497,958	595,239
Total assets held for sale	7,590,352	18,311,958
LIABILITIES HELD FOR SALE	'	'
Operator Payable	486,088	126,947
Eagle Ford asset purchase payable	190,000	190,000
Due to the Caltex bankruptcy estate	123,202	123,202
Current liabilities held for sale	799,290	440,149
Due to the Caltex bankruptcy estate	834,054	771,717
Asset retirement obligations	2,683,807	2,485,007
Non-current liabilities held for sale	$3,517,861	$3,256,724

DISPOSITION_AND_IMPAIRMENT_OF_3

DISPOSITION AND IMPAIRMENT OF OIL AND GAS INTERESTS (Details Textual) (USD $)	12 Months Ended		3 Months Ended			1 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Sep. 30, 2013	31-May-12	Feb. 28, 2014
			Eagle Ford Oil Co Inc [Member]	Eagle Ford Oil Co Inc [Member]	Eagle Ford Oil Co Inc [Member]	Eagle Ford Oil Co Inc [Member]
						Subsequent Event [Member]
Disposition And Impairment Of Oil And Gas Interests [Line Items]	'	'	'	'	'	'
Business Combination, Contingent Consideration, Liability	'	'	'	$300,000	'	'
Working Interest Acquired	80.00%	'	'	100.00%	80.00%	'
Business Combination Contingent Consideration Payable Due One	'	'	'	25,000	'	'
Business Combination Contingent Consideration Payable Due Two	'	'	'	125,000	'	'
Business Combination Contingent Consideration Payable Due Three	'	'	'	150,000	'	'
Payments To Business Combination Contingent Consideration	'	'	15,000	25,000	'	'
Written Off Of Investment	'	'	40,000	'	'	'
Financing Receivable, Gross	'	'	'	'	'	500,000
Working Interest Sold Percentage	'	'	'	'	'	10.00%
Royalty Interest Percentage	'	'	'	'	'	25.00%
Depletion, Total	26,408	24,377	'	'	'	'
Depreciation, Total	97,284	73,107	'	'	'	'
Results of Operations, Impairment of Oil and Gas Properties	10,607,064	0	'	'	'	'
Oil And Gas Properties Proved Reserves	'	'	1,571,000	'	'	'
Oil And Gas Properties Unproved Reserves	'	'	$1,862,117	'	'	'

FURNITURE_FIXTURES_AND_EQUIPME2

FURNITURE, FIXTURES AND EQUIPMENT (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Furniture, Fixtures And Equipment [Line Items]	'	'
Office furniture and equipment	$14,939	$0
Accumulated depreciation	0	0
Property Plant and Equipment Other Net	$14,939	$0

NOTES_AND_ADVANCES_PAYABLE_Det

NOTES AND ADVANCES PAYABLE (Details Textual) (USD $)

1 Months Ended

2 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

Jan. 31, 2013

Apr. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Aug. 01, 2013

25-May-12

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Mar. 31, 2012

Dec. 22, 2012

Feb. 24, 2012

Dec. 31, 2012

Feb. 24, 2012

Dec. 31, 2013

Feb. 14, 2012

Apr. 30, 2012

Apr. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

21-May-12

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Eagle Ford Oil Co Inc [Member]

Eagle Ford Oil Co Inc [Member]

Eagle Ford Oil Co Inc [Member]

Pan American Oil Company, Llc [Member]

Pan American Oil Company, Llc [Member]

Unaffiliated Entities [Member]

Unaffiliated Entities [Member]

Unsecured Promissory Note [Member]

Unsecured Promissory Note [Member]

Unsecured Promissory Note [Member]

Loan Agreements [Member]

Loan Agreements [Member]

Two Promissory Note [Member]

Two Promissory Note [Member]

Two Promissory Note [Member]

Sale Of Promissory Note [Member]

Sale Of Promissory Note One [Member]

Sale Of Promissory Note One [Member]

Sale Of Promissory Note One [Member]

Sale Of Promissory Note Two [Member]

Sale Of Promissory Note Two [Member]

Sale Of Promissory Note Three [Member]

Sale Of Promissory Note Three [Member]

Michael Garnick [Member]

Notes And Advances Payable [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Bridge Loan

'

'

'

'

'

'

'

'

'

'

'

$1,900,000

'

$600,000

'

'

$1,300,000

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

6.00%

'

'

5.00%

5.00%

8.00%

'

'

'

'

'

10.00%

'

10.00%

'

6.00%

'

'

8.00%

'

3.00%

'

'

6.00%

'

6.00%

'

Debt Instrument, Maturity Date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

31-Dec-14

'

'

'

'

'

30-Apr-17

'

'

31-Dec-12

'

31-Dec-13

'

Advances to Affiliate

'

'

'

90,000

'

'

'

'

90,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Convertible, Stock Price Trigger

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$2.50

'

'

'

'

'

'

'

'

'

'

Interest Expense, Debt

'

'

115,988

73,529

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Convertible, Conversion Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.75

'

'

'

'

'

'

Proceeds Raised In Debt Or Equity

'

1,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,500,000

'

1,500,000

'

Short-term Debt

'

'

'

'

'

'

'

'

'

'

350,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Advances payable

'

'

90,704

90,704

'

'

'

'

'

90,704

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from sale of promissory note

300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

750,000

'

'

300,000

'

2,902,600

Purchase Price To Acquire

'

'

'

'

'

80.00%

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Unamortized Discount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

750

'

'

'

'

'

'

150,000

'

13,829

'

'

'

'

Proceeds From Issuance Of Promissory Paper

'

110,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition Intent For Debt Description

'

'

'In January 2013, the Company and 0947388 BC Ltd. (094) entered into a letter of intent for 094 to farm into the Edwards formation assets acquired through its acquisition of Pan American Oil Company, LLC (see Note 2) and Numa Luling, LLC (see Note 4) and also the 80% interest in certain leasehold interests acquired from Eagle Ford Oil Co., Inc. (see Note 4). The Company and 094 were unable to successfully negotiate a farm-in by 094. At the time of entering the letter of intent, 094 paid a deposit of $300,000. That deposit remains outstanding as of December 31, 2013 and is included in short term notes payable.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period Shares Issued For Along With Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Face Amount

'

'

'

'

290,000

'

'

'

'

'

'

'

'

'

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Fee Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

Proceeds from Issuance of Long-term Debt, Total

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,500,000

'

'

'

'

'

'

'

'

'

'

Debt Conversion, Converted Instrument, Shares Issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,500,000

'

'

'

'

'

'

'

'

'

'

Loan Processing Fee

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

110,000

'

'

'

Business Acquisition, Cost of Acquired Entity, Other Noncash Considerations

'

'

'

'

'

225,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt, Gross

'

'

1,267,600

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,500,000

2,500,000

'

750,000

'

750,000

'

300,000

'

1,635,000

'

Debt Instrument, Maturity Date Range, Start

'

'

31-Jan-14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Maturity Date Range, End

'

'

30-Sep-14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loans and Leases Receivable, Related Parties

'

'

'

'

'

'

$190,000

$190,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

PREFERRED_STOCK_Details_Textua

PREFERRED STOCK (Details Textual) (USD $)

12 Months Ended

43 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

4 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Feb. 29, 2012

Dec. 16, 2011

Sep. 29, 2010

Jun. 21, 2010

Dec. 31, 2013

Mar. 31, 2012

Sep. 30, 2012

Dec. 31, 2013

Jul. 30, 2013

Jun. 30, 2012

Sep. 30, 2010

Dec. 31, 2013

Dec. 31, 2012

Series A Preferred Stock [Member]

Series A Preferred Stock [Member]

Series C Preferred Stock [Member]

Series C Preferred Stock [Member]

Series C Preferred Stock [Member]

Series B Preferred Stock [Member]

Series B Preferred Stock [Member]

Series B Preferred Stock [Member]

Series B Preferred Stock [Member]

Private Placement [Member]

Preferred Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period, Shares, Acquisitions

'

'

'

'

'

'

'

5,500,000

'

'

'

'

3,250,000

'

3,250,000

3,250,000

Preferred Stock, Dividend Rate, Percentage

'

'

'

'

'

'

'

3.00%

'

'

5.00%

'

'

'

'

'

Stock Issued During Period, Shares, New Issues

'

'

'

'

'

'

'

'

10,000,000

492,000

'

'

'

0

'

'

Share Price

'

'

'

'

'

$0.03

$0.00

$1

'

'

$1

'

'

'

$1

'

Convertible Preferred Stock, Shares Issued upon Conversion

'

'

'

'

'

'

'

'

'

'

1.11

'

'

'

1.33

'

Common Stock, Conversion Basis

'

'

'

'

'

'

'

'In addition, should the common stock of the Company trade in any over the counter market above $1.75 per share for a period of at least 30 consecutive trading days, the Company have an initial public offering of any class of securities in which gross proceeds are in excess of $50 million or consummate a merger in which the existing Company shareholders obtain less than 50% of the voting control of the combined entity,

'

'

'

'

'

'

'

'

Preferred dividends

$165,000

$144,375

$309,375

'

'

'

'

$309,375

'

'

'

'

'

'

'

'

Preferred Stock Conversion Terms Minimum Trading Price

'

'

'

'

'

'

'

$1.75

'

'

$1.75

'

'

'

$1.75

'

Preferred Stock Conversion Terms Minimum Proceeds From Initial Public Offering

'

'

'

'

'

'

'

50,000,000

'

'

50,000,000

'

'

'

50,000,000

'

Preferred Stock, Shares Authorized

'

'

'

'

30,000,000

'

'

'

'

'

'

12,000,000

'

'

5,000,000

5,000,000

Preferred Stock, Par Or Stated Value Per Share

'

'

'

'

$0.00

'

'

'

'

'

'

$0.00

'

'

$0.00

$0.00

Proceeds from Issuance Initial Public Offering

'

'

'

'

'

'

'

'

'

$492,000

'

'

'

'

'

'

Class of Warrant or Right, Exercise Price of Warrants or Rights

'

'

'

1.5

'

'

'

'

'

2.5

'

'

'

'

'

'

Warrants Maturity Term

'

'

'

'

'

'

'

'

'

'3 years

'

'

'

'

'

'

COMMON_STOCK_Details_Textual

COMMON STOCK (Details Textual) (USD $)

1 Months Ended

12 Months Ended

43 Months Ended

1 Months Ended

0 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Feb. 28, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

31-May-12

Mar. 28, 2012

Feb. 29, 2012

Dec. 16, 2011

Dec. 16, 2011

Dec. 16, 2011

Jan. 31, 2013

Feb. 14, 2012

Dec. 31, 2012

Jan. 31, 2013

Jul. 31, 2012

Dec. 31, 2012

Dec. 16, 2011

Dec. 16, 2011

Dec. 31, 2013

Dec. 31, 2012

Minimum [Member]

Maximum [Member]

Series Preferred Stock [Member]

Private Placement [Member]

Private Placement [Member]

Common Stock [Member]

Common Stock [Member]

Common Stock [Member]

Common Stock [Member]

Common Stock [Member]

Warrant [Member]

Warrant [Member]

Minimum [Member]

Maximum [Member]

Common Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage Of Common Stock Outstanding

'

'

'

'

15.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock, Shares Authorized

'

120,000,000

120,000,000

120,000,000

'

'

'

'

75,000,000

120,000,000

'

'

'

'

'

'

'

'

'

'

Common Stock, Par Or Stated Value Per Share

'

$0.00

$0.00

$0.00

'

'

'

'

$0.00

$0.00

'

'

'

'

'

'

'

'

'

'

Preferred Stock, Shares Authorized

'

'

'

'

'

'

'

30,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders Equity Note, Stock Split

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2-for-1

'30-for-1

'

'

Units Offering Price Per Unit

'

'

'

'

'

'

'

'

'

'

'

$0.75

'

'

'

'

'

'

'

'

Class of Warrant or Right, Exercise Price of Warrants or Rights

'

'

'

'

'

'

1.5

'

'

'

'

'

'

'

'

'

'

'

'

'

Class Of Warrant Or Rights Exercise Period

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years

Percentage Of Commission Fee

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Issuance of Private Placement

'

'

$2,656,250

'

'

'

'

'

'

'

'

'

$500,000

'

'

'

'

'

'

'

Accrued Sales Commission

'

'

265,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Professional Fees

'

605,316

1,273,430

1,878,746

'

'

'

'

'

'

'

'

41,000

'

'

'

'

'

'

'

Common Stock Shares Cancelled

'

'

'

'

'

66,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period, Shares, Conversion of Units

'

'

'

'

'

'

'

'

'

'

'

6,000,000

666,666

'

'

'

'

'

'

'

Stock Issued During Period, Shares, Issued for Services

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000

100,000

'

'

'

'

Stock Issued During Period Trading Price Issued For Services

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.86

'

'

'

'

'

Warrants Issued During Period Warrants Issued For Services

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

500,000

Warrants Issued During Period Exercise Of Warrants Issued For Services

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.5

Fair Value Assumptions, Exercise Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$99

Fair Value Assumptions, Expected Volatility Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28.20%

Fair Value Assumptions, Risk Free Interest Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.01%

Warrants Issued During Period Value Issued For Services

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$33,650

Conversion of Stock, Shares Converted

'

'

'

'

'

'

'

'

'

'

110,000

'

'

110,000

'

'

'

'

'

'

Preferred Stock, Par Or Stated Value Per Share

'

'

'

'

'

'

'

$0.00

'

'

'

'

'

'

'

'

'

'

'

'

INCOME_TAXES_Details

INCOME TAXES (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Line Items]	'	'
Federal	$0	$0
State and local	0	0
Foreign	0	0
Total income tax expense	0	0
Current	0	0
Deferred	0	0
Total Income Tax Expense	$0	$0

INCOME_TAXES_Details_1

INCOME TAXES (Details 1)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Line Items]	'	'
Statutory U.S. federal rate	35.00%	35.00%
Permanent differences	0.00%	0.00%
Valuation allowance	35.00%	35.00%
Provision for income tax expense (benefit)	0.00%	0.00%

INCOME_TAXES_Details_2

INCOME TAXES (Details 2) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Deferred Tax Assets:	'	'
Net Operating Loss Carryforwards	$2,401,000	$1,204,000
Non-cash compensation	0	0
Provision for fixed asset impairment	3,683,000	0
Accrued Liabilities	0	0
Total Deferred Tax Assets	6,084,000	1,204,000
Deferred Tax Liabilities:	'	'
Total Deferred Tax Liabilities	0	0
Net Deferred Tax Asset	6,084,000	1,204,000
Valuation Allowance	-6,084,000	-1,204,000
Net Deferred Tax Asset	$0	$0

INCOME_TAXES_Details_Textual

INCOME TAXES (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Line Items]	'	'
Operating Loss Carryforwards	$6,940,000	$3,440,000
Deferred Tax Assets, Valuation Allowance	6,084,000	1,204,000
Valuation Allowance, Deferred Tax Asset, Change in Amount	$4,880,000	$1,197,000
Operating Loss Carry forwards Expiration Period	'expire in 2030	'expire in 2030

SUBSEQUENT_EVENTS_Details_Text

SUBSEQUENT EVENTS (Details Textual) (USD $)

12 Months Ended

43 Months Ended

1 Months Ended

3 Months Ended

2 Months Ended

3 Months Ended

3 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Aug. 01, 2013

Apr. 30, 2013

Jan. 31, 2013

Jan. 31, 2013

Mar. 31, 2014

Apr. 30, 2014

Mar. 31, 2014

Mar. 31, 2014

Feb. 28, 2014

Mar. 31, 2014

Common Stock [Member]

Series Preferred Stock [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

ShareHolder [Member]

Chief Executive Officer [Member]

Common Stock [Member]

Series Preferred Stock [Member]

Eagle Ford Oil Co Inc [Member]

Subsequent Event [Member]

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

5.00%

6.00%

'

'

'

'

'

'

10.00%

'

Conversion of Stock, Shares Converted

'

'

'

'

'

110,000

110,000

'

'

550,000

500,000

'

'

Debt Instrument, Face Amount

'

'

'

$290,000

'

'

'

'

'

'

'

$500,000

'

Proceeds From Related Party Debt

1,267,601

0

1,467,601

'

'

'

'

'

11,000

'

'

'

89,000

Proceeds From UnRelated Party Debt

'

'

'

'

'

'

'

$37,000

'

'

'

'

'

SUPPLEMENTAL_OIL_AND_GAS_DISCL2

SUPPLEMENTAL OIL AND GAS DISCLOSURE (unaudited) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
	MBbls	MBbls
Reserve Quantities [Line Items]	'	'
1-Jan	1,175	0
Purchase of properties	0	1,176
Revisions of previous estimates	-925	0
Extension, discoveries, other estimates	0	0
Production	-1	-1
Disposition of properties	0	0
31-Dec	249	1,175

SUPPLEMENTAL_OIL_AND_GAS_DISCL3

SUPPLEMENTAL OIL AND GAS DISCLOSURE (unaudited) (Details 1)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MBbls	MBbls	MBbls
Reserve Quantities [Line Items]	'	'	'
Proved developed not producing	249	249	'
Proved undeveloped	0	926	'
Total proven	249	1,175	0

SUPPLEMENTAL_OIL_AND_GAS_DISCL4

SUPPLEMENTAL OIL AND GAS DISCLOSURE (unaudited) (Details 2) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]	'	'
Revenue	$120,153	$101,556
Operating expenses (lifting costs and workover expenses)	1,485,201	799,386
Depletion and depreciation	26,408	24,377
Impairment of oil and gas properties	10,607,064	0
Operating loss	-11,998,520	-722,207
Income tax provision (net of valuation allowance)	0	0
Results of operations for oil and gas properties	($11,998,520)	($722,207)

SUPPLEMENTAL_OIL_AND_GAS_DISCL5

SUPPLEMENTAL OIL AND GAS DISCLOSURE (unaudited) (Details 3) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]	'	'
Unproved	$0	$0
Proved	9	16,024
Exploration	0	0
Development	0	1,717
Total costs incurred	$9	$17,741

SUPPLEMENTAL_OIL_AND_GAS_DISCL6

SUPPLEMENTAL OIL AND GAS DISCLOSURE (unaudited) (Details 4) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]	'	'
Proved	$15,888	$17,741
Unproved	1,862	0
Total capitalized costs	17,750	17,741
Accumulated depletion, depreciation and impairment	-10,884	-24
Net capitalized costs	$6,866	$17,717

SUPPLEMENTAL_OIL_AND_GAS_DISCL7

SUPPLEMENTAL OIL AND GAS DISCLOSURE (unaudited) (Details 5) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'	'
Future cash inflows	$22,407	$105,600
Less related future:	'	'
Production costs	-5,678	-18,098
Development costs	-2,625	-18,825
Future net cash flows before income taxes	14,104	68,677
Future income taxes	0	-24,037
Future net cash flows	14,104	44,640
10% annual discount for estimating timing of cash flows	-4,170	-14,496
Standardized measure of discounted future net cash flows	$9,934	$30,144

SUPPLEMENTAL_OIL_AND_GAS_DISCL8

SUPPLEMENTAL OIL AND GAS DISCLOSURE (unaudited) (Details 6) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Schedule Of Changes in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Line Items]	'	'
Net changes in sales and transfer prices and in production (lifting) costs related to future production	$0	$0
Changes in estimated future development costs	0	0
Sales and transfers of oil and gas produced during the period	-122	-100
Net change due to extensions, discoveries and improved recovery	0	30,244
Net change due to purchases and sales of minerals in place	0	0
Net change due to revisions in quantity estimates	-20,088	0
Previously estimated development costs incurred during the period	0	0
Accretion of discount	0	0
Other - unspecified	0	0
Net change in income taxes	0	0
Aggregate change in the standardized measure of discounted net cash flows for the year	($20,210)	$30,144

SUPPLEMENTAL_OIL_AND_GAS_DISCL9

SUPPLEMENTAL OIL AND GAS DISCLOSURE (unaudited) (Details Textual)	12 Months Ended
	Dec. 31, 2013
Supplemental Oil and Gas Disclosure [Line Items]	'
Discount Rate On Oil and Gas Reserves	10.00%