TransCoastal 10-K 31 Mar 15 2014 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2014	Mar. 31, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	TransCoastal Corp
Document Type	10-K
Current Fiscal Year End Date	-19
Entity Common Stock, Shares Outstanding		29,334,264
Entity Public Float		$8,800,879
Amendment Flag	FALSE
Entity Central Index Key	1046057
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Smaller Reporting Company
Entity Well-known Seasoned Issuer	No
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets
Cash and cash equivalents	$128	$432
Accounts receivable	225	436
Current derivative assets	556
Other current assets		20
Total current assets	909	888
Oil and natural gas properties and other property and equipment
Oil and natural gas properties, full cost method, net of accumulated depletion	23,410	23,600
Other property and equipment, net of accumulated depreciation	398	470
Total oil and natural gas properties and other equipment, net	23,808	24,070
Other assets
Goodwill	485	485
Other non-current assets	223	387
Total other assets	708	872
Total assets	25,425	25,830
Current liabilities
Accounts payable and accrued liabilities	944	1,620
Dividends payable	47
Current asset retirement obligations	113	107
Current derivative liabilities		125
Current maturities of notes payable	15,829	17,512
Total current liabilities	16,933	19,364
Long-term liabilities
Notes payable	1,477	56
Stock to be issued	845	2,496
Asset retirement obligations	877	852
Derivative liabilities		18
Total long-term liabilities	3,199	3,422
Commitments and contingencies
Shareholders' equity
Preferred stock
Common stock, $.001 par value; 250,000,000 shares authorized; 29,334,264 and 22,453,773, respectively, shares issued and outstanding	29	23
Additional paid-in-capital	49,680	45,592
Accumulated deficit	-44,417	-42,572
Total shareholders' equity	5,293	3,044
Total liabilities and shareholders' equity	25,425	25,830
Series G Preferred Stock [Member]
Shareholders' equity
Preferred stock		1
Series H Preferred Stock [Member]
Shareholders' equity
Preferred stock	$1

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parentheticals) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Jul. 30, 2013	Jul. 29, 2013
Preferred stock, par value (in Dollars per share)	$0.00	$0.00
Preferred stock, shares authorized	25,000,000	25,000,000
Common stock, par value (in Dollars per share)	$0.00	$0.00
Common stock, shares authorized	250,000,000	250,000,000
Common stock, shares issued	29,334,264	22,453,773
Common stock, shares outstanding	29,334,264	22,453,773	178,224	35,644,696
Series G Preferred Stock [Member]
Preferred Stock, shares issued	0	687,500
Preferred Stock, shares outstanding	0	687,500
Series H Preferred Stock [Member]
Preferred Stock, shares issued	1,125,000	0
Preferred Stock, shares outstanding	1,125,000	0

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Revenues
Oil, natural gas, and related product sales	$3,818	$3,728
Derivative income (loss)	720	-269
Other revenue	17	163
Total revenues	4,555	3,622
Expenses
Loss on turn-key contracts		1,468
Lease operating	888	1,147
Depreciation, depletion and amortization	537	704
Accretion of discount on asset retirement obligations	31	45
General and administrative	4,116	3,661
Total expenses	5,570	7,025
Operating loss	-1,015	-3,403
Other income (expense)
Interest expense	-774	-709
Other income (expense)	93	59
Total other expense, net	-681	-650
Net loss	-1,695	-4,053
Basic/Diluted loss per share:
Net loss per basic/diluted common share (in Dollars per share)	($0.07)	($0.18)
Weighted average basic/diluted common shares outstanding (in Shares)	24,435,524	22,527,107
Paid [Member]
Other income (expense)
Dividends	-103
Declared and Unpaid [Member]
Other income (expense)
Dividends	-47
Net loss attributable to common shareholders	($1,845)

Consolidated_Statements_of_Cha

Consolidated Statements of Changes in Shareholders' Equity (USD $)		Series A Preferred Stock [Member]	Series A Preferred Stock [Member]	Series A Preferred Stock [Member]	Series A Preferred Stock [Member]	Series F Preferred Stock [Member]	Series F Preferred Stock [Member]	Series F Preferred Stock [Member]	Series F Preferred Stock [Member]	Series G Preferred Stock [Member]	Series G Preferred Stock [Member]	Series G Preferred Stock [Member]	Series G Preferred Stock [Member]	Series G Preferred Stock [Member]	Series G Preferred Stock [Member]	Series H Preferred Stock [Member]	Series H Preferred Stock [Member]	Series H Preferred Stock [Member]	Series H Preferred Stock [Member]	Series H Preferred Stock [Member]	Constructive Dividends on Series A Preferred Stock [Member]	Constructive Dividends on Series A Preferred Stock [Member]	Constructive Dividends on Series G Preferred Stock [Member]	Constructive Dividends on Series G Preferred Stock [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Total
In Thousands, except Share data		Common Stock [Member]	Preferred Stock [Member]	Additional Paid-in Capital [Member]	USD ($)	Common Stock [Member]	Preferred Stock [Member]	Additional Paid-in Capital [Member]		Common Stock [Member]	Preferred Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Paid [Member]	USD ($)	Preferred Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Declared and Unpaid [Member]	USD ($)	Additional Paid-in Capital [Member]	USD ($)	Additional Paid-in Capital [Member]	USD ($)	USD ($)	USD ($)	USD ($)	USD ($)
		USD ($)	USD ($)	USD ($)		USD ($)	USD ($)	USD ($)		USD ($)	USD ($)	USD ($)	Paid [Member]	USD ($)		USD ($)	USD ($)	Declared and Unpaid [Member]	USD ($)		USD ($)		USD ($)
													USD ($)					USD ($)
Balance, beginning of period at Dec. 31, 2012	[1]						$4																			$43,908	($38,519)	$5,393
Balance, beginning of period (in Shares) at Dec. 31, 2012	[1]		37,500				3,721,036
Recapitalization with Claimsnet.com, Inc.																										-1,602		-1,602
Recapitalization with Claimsnet.com, Inc. (in Shares)																									178,250
Spin-off of ANC Holdings, Inc.																										1,602		1,602
Issuance of stock				679	679						1	2,440			2,441
Issuance of stock (in Shares)			206,250		206,250						687,250				687,250
Dividends					-266										-1,756						-266	-266	-1,756	-1,756
Conversion of preferred stock		1		-1		21	-4	-17
Conversion of preferred stock (in Shares)		487,500	-243,750			21,323,978	-3,721,036
Issuance of common stock for deferred offering costs																										250		250
Issuance of common stock for deferred offering costs (in Shares)																									256,578
Forgiveness of notes payable, related party																										125		125
Stock based compensation																									1	269		270
Stock based compensation (in Shares)																									207,467
Series A preferred dividend payments				-39	-39
Net loss																											-4,053	-4,053
Balance, end of period at Dec. 31, 2013											1														23	45,592	-42,572	3,044
Balance, end of period (in Shares) at Dec. 31, 2013											687,250														22,453,773
Issuance of stock												603			603	1	923			924						1,209		1,209
Issuance of stock (in Shares)					0						603,000				603,000	1,125,000				1,125,000					825,829
Issuance of warrants exercised																									1	289		289
Issuance of warrants exercised (in Shares)																									1,335,000
Dividends													-103	-103				-47	-47
Conversion of preferred stock										3	-1				2
Conversion of preferred stock (in Shares)										2,580,500	-1,290,250
Stock based compensation																									2	667		669
Stock based compensation (in Shares)																									2,139,162
Net loss																											-1,695	-1,695
Balance, end of period at Dec. 31, 2014																$1									$29	$49,680	($44,417)	$5,293
Balance, end of period (in Shares) at Dec. 31, 2014																1,125,000									29,334,264
[1]	Balance is reflective of Claimsnet.com Inc.'s acquisition of TransCoastal Corporation on March 18, 2013 (as amended April 24, 2013) as discussed in Note 3.

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Cash flows from operating activities
Net loss	($1,695)	($4,053)
Adjustments to reconcile net loss to net cash and cash equivalents used in operating activities:
Depreciation, depletion and amortization	537	704
Stock based compensation	667	270
Accretion of discount on asset retirement obligations	31	45
Loss on turn-key contracts		1,468
(Gain) loss on derivative assets and liabilities	-822	165
Increase (decrease) in cash and cash equivalents attributable to changes in operating assets and liabilities
Accounts receivable	211	-740
Other current assets	20
Other non-current assets	287	-17
Accounts payable and accrued liabilities	-717	504
Net cash and cash equivalents used in operating activities	-1,481	-1,654
Cash flows from investing activities
Development of oil and natural gas properties	-586	-716
Acquisition of oil and natural gas properties		-140
Proceeds from disposition of oil and natural gas properties	311
Acquisition of other property and equipment		-15
Net cash and cash equivalents used in investing activities	-275	-871
Cash flows from financing activities
Borrowings under notes payable	1,587	1,778
Repayments of notes payable	-1,850	-6
Proceeds from stock to be issued		8
Proceeds from warrants exercised	289
Payment of deferred offering costs		-15
Net cash and cash equivalents provided by financing activities	1,449	2,824
Net increase (decrease) in cash and cash equivalents	-304	299
Cash and cash equivalents, beginning of year	432	133
Cash and cash equivalents, end of year	128	432
Supplemental disclosure of cash flow information
Cash paid during the year for interest	774	740
Supplemental disclosure of non-cash investing transactions
Capitalized asset retirement costs		37
Common stock issued for deferred offering costs		250
Net assets acquired and liabilities assumed through TransCoastal acquisition		1,602
Settlement of notes payable through sale of non-oil and gas assets and liabilities		1,602
Forgiveness of notes payable, related party		125
Issuance of common stock through settlement of stock to be issued liability	1,653
Dividend declared but not paid	47
Series A Preferred Stock [Member]
Cash flows from financing activities
Proceeds from issuance of preferred stock, net of constructive dividend		413
Dividends on preferred stock		-39
Supplemental disclosure of non-cash investing transactions
Conversion of preferred stock		1
Series G Preferred Stock [Member]
Cash flows from financing activities
Proceeds from issuance of preferred stock, net of constructive dividend	603	685
Dividends on preferred stock	-103
Supplemental disclosure of non-cash investing transactions
Conversion of preferred stock	2
Series H Preferred Stock [Member]
Cash flows from financing activities
Proceeds from issuance of preferred stock, net of constructive dividend	923
Series F Preferred Stock [Member]
Supplemental disclosure of non-cash investing transactions
Conversion of preferred stock		21
Acquisition of Oil and Gas Properties through Notes Payable [Member]
Supplemental disclosure of non-cash investing transactions
Acquisition of oil and natural gas properties and property and equipment		322
Acquisition of Oil and Natural Gas Properties through Stock to Be Issued [Member]
Supplemental disclosure of non-cash investing transactions
Acquisition of oil and natural gas properties and property and equipment		397
Acquisition of Other Property and Equipment through Notes Payable [Member]
Supplemental disclosure of non-cash investing transactions
Acquisition of oil and natural gas properties and property and equipment		$74

Note_1_Organization_and_Nature

Note 1 - Organization and Nature of Operations	12 Months Ended
	Dec. 31, 2014
Disclosure Text Block [Abstract]
Business Description and Basis of Presentation [Text Block]	1	Organization and nature of operations
	Prior to May 9, 2013, Claimsnet.com, Inc.’s (“Claimsnet”) business plan was to develop an electronic commerce company engaged in healthcare transaction processing for the medical and dental industries by means of the internet. On May 9, 2013, Claimsnet acquired a majority interest in TransCoastal Corporation (“TransCoastal”), a Texas corporation through an Acquisition Agreement. Claimsnet issued a total of 3,721,036 shares of Series F Preferred Stock, with an additional 194,920 Series F Preferred Stock to be issued, in consideration for the common stock of TransCoastal. Each share of Series F Preferred Stock issued has the attribute of having the voting right equal to 1,170.076 shares of common stock thereby giving the selling TransCoastal stockholders control of the corporation with the ability to vote 99.2% of all the votes eligible to vote for any matter brought before our equity holders.
	Claimsnet acquired TransCoastal under an acquisition agreement (the “Acquisition Agreement”), dated March 18, 2013, as amended by the Amended Acquisition Agreement, dated April 24, 2013, through the issuance of shares of our convertible Series F preferred stock. This resulted in the owners of TransCoastal (the “accounting acquirer”) having actual or effective operating control of Claimsnet after the transaction, with the shareholders of Claimsnet (the “legal acquirer”) continuing only as passive investors. TransCoastal is an oil and gas exploration and production company focused primarily in the development of oil and gas reserves in Texas and the Southwest region of the United States. Effective on the date of acquisition, TransCoastal became a Delaware Corporation. TransCoastal, and its wholly owned subsidiary, CoreTerra Operating, LLC (“CTO”), are referred to as the “Company”.
	Pursuant to the Amended Acquisition Agreement, on June 27, 2013, the Company placed, at the time of closing of the acquisition, all of the assets and liabilities constituting the current non-oil and gas assets of our business operations into a separate wholly-owned subsidiary of the Company, ANC Holdings, Inc. (“ANC Holdings”), and sold that subsidiary to certain debt holders of the Company, who were affiliates of Claimsnet, in consideration for cancellation by such debt holders of the Company indebtedness owed to them.
	Additionally, during the year ended December 31, 2013, TransCoastal Partners LLC, an entity under common control of the Company, contributed all of its net assets and liabilities, which approximated $700 at the date of contribution, to the Company. The consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (“GAAP”) and are presented in accordance with Accounting Standard Codification (“ASC”) 805, Business Combinations, which requires that entities under common control be reflected at their historical cost. Accordingly, the accompanying consolidated financial statements reflect the historical combined results of the common controlled entity prior to the reverse recapitalization date.
	Claimsnet formally changed its name to TransCoastal Corporation and declared a reverse 200 to 1 stock split effective July 1, 2013.

Note_2_Going_Concern_Considera

Note 2 - Going Concern Consideration	12 Months Ended
	Dec. 31, 2014
Going Concern [Abstract]
Going Concern [Text Block]	2	Going concern consideration
	The consolidated financial statements have been prepared assuming the Company will continue as a going concern. As of December 31, 2014, the Company had a working capital deficit of approximately $15,429 and an accumulated deficit of approximately $44,369. For the year ended December 31, 2014, the Company had a net loss of approximately $1,695 and used cash in operations of approximately $1,481. The working capital deficit at December 31, 2014 is primarily the result of the Company’s line of credit with Green Bank being classified as current. These conditions raise substantial doubt about the Company’s ability to continue as a going concern. If the Company is unable to obtain additional debt or equity financing, it may require the Company to liquidate a portion of its oil and natural gas properties to meet its liquidity needs, which could affect the Company’s long-term strategic plan and require the Company to liquidate certain oil and natural gas properties at an amount less than would normally be achieved if sold in the ordinary course of business. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.

Note_3_Summary_of_Significant_

Note 3 - Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Significant Accounting Policies [Text Block]	3	Summary of significant accounting policies
	Basis of Presentation
	The consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (“GAAP”).
	These consolidated financial statements were approved by management and available for issuance on March 31, 2014. Subsequent events have been evaluated through this date.
	Principles of Consolidation
	The accompanying consolidated financial statements include the accounts of TransCoastal and its wholly owned subsidiary, CTO. All intercompany transactions and balances have been eliminated in consolidation.
	Fair Value Measurements
	The Company has adopted and follows ASC 820, Fair Value Measurements and Disclosures, for measurement and disclosures about fair value of its financial instruments.  ASC 820 establishes a framework for measuring fair value in GAAP, and expands disclosures about fair value measurements. To increase consistency and comparability in fair value measurements and related disclosures, ASC 820 establishes a fair value hierarchy which prioritizes the inputs to valuation techniques used to measure fair value into three (3) broad levels.  The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities and the lowest priority to unobservable inputs.  The three (3) levels of fair value hierarchy defined by ASC 820 are:
	Level 1 — Inputs are unadjusted, quoted prices in active markets for identical assets or liabilities at the measurement date.
	Level 2 — Inputs (other than quoted market prices included in Level 1) are either directly or indirectly observable for the asset or liability through correlation with market data at the measurement date and for the duration of the instrument’s anticipated life.
	Level 3 — Inputs reflect management’s best estimate of what market participants would use in pricing the asset or liability at the measurement date. Consideration is given to the risk inherent in the valuation technique and the risk inherent in the inputs to the model. Valuation of instruments includes unobservable inputs to the valuation methodology that are significant to the measurement of fair value of assets or liabilities.
	As defined by ASC 820, the fair value of a financial instrument is the amount at which the instrument could be exchanged in a current transaction between willing parties, other than in a forced or liquidation sale, which was further clarified as the price that would be received to sell an asset or paid to transfer a liability (“an exit price”) in an orderly transaction between market participants at the measurement date.  The carrying amounts of the Company’s financial assets and liabilities, such as cash and cash equivalents, oil and natural gas sales receivable, and accounts payable and accrued liabilities, approximate their fair values because of the short maturity of these instruments.
	Cash and Cash Equivalents
	The Company considers all highly-liquid debt instruments with original maturities of three months or less to be cash equivalents. As of December 31, 2014 and 2013, the Company held approximately $127 and $63, respectively, in cash equivalents.
	The Company maintains its cash balances in financial institutions which are insured by the Federal Deposit Insurance Corporation (“FDIC”). The interest bearing cash accounts maintain FDIC coverage of up to $250 per institution. As of December 31, 2014 and 2013, the Company had $0 and $44, respectively, in excess of its FDIC coverage.
	Accounts Receivable
	Accounts receivable is comprised of billings for services as the operator on certain wells, that TransCoastal has no working interest in, and accrued natural gas and crude oil sales. The Company performs ongoing credit evaluations of its customers’ and extends credit to virtually all of its customers. Credit losses to date have not been significant and have been within management’s expectations.  In the event of complete non-performance by the Company’s customers, the maximum exposure to the Company is the outstanding accounts receivable, net balance at the date of non-performance. The amounts billed to third parties for services as the operator have rights of offset against revenues generated from the sale of oil and gas commodities. For the years ended December 31, 2014 and 2013, the Company had no bad debt expense or allowance.
	Derivative Activities
	The Company utilized oil and natural gas derivative contracts to mitigate its exposure to commodity price risk associated with its future oil and natural gas production. These derivative contracts have historically consisted of options, in the form of price floors or collars. The Company’s derivative financial instruments are recorded on the consolidated balance sheets as either an asset or a liability measured at fair value. The Company does not apply hedge accounting to its oil and natural gas derivative contracts and accordingly the changes in the fair value of these instruments are recognized in the consolidated statements of operations in the period of change.
	The Company’s derivative instruments are issued to manage the price risk attributable to our expected natural gas and oil production. While there is risk that the financial benefit of rising natural gas and oil prices may not be captured, Company management believes the benefits of stable and predictable cash flow are more important. Every unsettled derivative instrument is recorded on the accompanying consolidated balance sheets as either an asset or a liability measured at its fair value.
	Changes in a derivative’s fair value are recognized in earnings unless specific hedge accounting criteria are met. Cash flows from natural gas and oil derivative contract settlements are reflected in operating activities in the accompanying consolidated statements of cash flows.
	Realized and unrealized gains and losses on derivatives are accounted for using the mark-to-market accounting method. We recognize all unrealized and realized gains and losses related to these contracts in each period in derivative gains or (losses) in the accompanying consolidated statements of operations.
	Oil and Gas Natural Gas Properties
	The Company uses the full-cost method of accounting for its oil and natural gas producing activities as further defined under ASC 932, Extractive Activities - Oil and natural gas. Under these provisions, all costs incurred for both successful and unsuccessful exploration and development activities, including salaries, benefits and other internal costs directly identified with these activities, and oil and natural gas property acquisitions are capitalized. All costs related to production, general corporate overhead or similar activities are expensed as incurred.
	Proved properties are amortized using the units of production method (“UOP”). The UOP calculation, in its simplest terms, multiplies the percentage of estimated proved reserves produced at year end by the cost of those reserves.
	The amortization base in the UOP calculation includes the sum of proved property, net of accumulated depreciation, depletion and amortization (“DD&A”), estimated future development costs (future costs to access and develop reserves) and asset retirement costs that are not already included in oil and natural gas property, less related salvage value.
	The cost of unproved properties and properties under development are excluded from the amortization calculation until it is determined whether or not proved reserves can be assigned to such properties or until development projects are placed in service. Geological and geophysical costs not associated with specific properties are recorded to proved properties. Unproved properties and properties under development are reviewed for impairment at least quarterly. In countries where proved reserves exist, exploratory drilling costs associated with dry holes are transferred to proved properties immediately upon determination that a well is dry and amortized accordingly. As of December 31, 2014 and 2013, no unproved properties or properties under development were included in the oil and natural gas properties of the accompanying consolidated financial statements.
	Proceeds from the sale or disposition of oil and natural gas properties are accounted for as a reduction to capitalized costs unless a significant portion (greater than 25 percent) of the Company’s reserve quantities in a particular country are sold, in which case a gain or loss is recognized in income. For the years ended December 31, 2014 and 2013, no gain or loss from the sale or disposition of oil and natural gas properties occurred.
	Under the full-cost method of accounting, the net book value of oil and natural gas properties, less related deferred income taxes, may not exceed a calculated “ceiling.” The ceiling limitation is the estimated after-tax future net cash flows from proved oil and natural gas reserves, discounted at 10 percent per annum based on industry standards and adjusted for cash flow hedges. Estimated future net cash flows exclude future cash outflows associated with settling accrued asset retirement obligations. Any excess of the net book value of proved oil and gas properties, less related deferred income taxes, over the ceiling is charged to expense and reflected as additional DD&A in the accompanying consolidated statements of operations. For the years ended December 31, 2014 and 2013, no impairment charge occurred.
	During the years ended December 31, 2014 and 2013, the Company determined $0 and $31, respectively, of interest costs were incurred during the development period of our wells, which is reflected as an increase to the Company’s full-cost pool in the accompanying consolidated balance sheets.
	Other Property and Equipment
	Other property and equipment, which includes buildings, field equipment, vehicles, and office equipment, is stated at cost less accumulated depreciation. Depreciation is computed using the straight-line method over the estimated useful lives of the assets. Vehicles and office equipment are generally depreciated over a useful life of five or six years, field equipment is generally depreciated over a useful life of ten years and buildings are generally depreciated over a useful life of twenty years.
	Impairment of Long-Lived Assets
	The Company assesses the impairment of long-lived assets when circumstances indicate that the carrying value may not be recoverable. The Company determines if impairment has occurred through adverse changes. When it is determined that the estimated future net cash flows of an asset will not be sufficient to recover its carrying amount, an impairment loss must be recorded to reduce the carrying amount to its estimated fair value. For the years ended December 31, 2014 and 2013, no circumstances indicated an unrecoverable carrying value of the long-lived assets.
	Goodwill
	Goodwill was generated as part of the CTO acquisition during the year ended December 31, 2011 and represents the excess of the purchase price over the estimated fair value of the net assets acquired in the acquisition. Goodwill is not amortized; rather, it is tested for impairment annually and when events or changes in circumstances indicate that fair value of a reporting unit with goodwill has been reduced below carrying value. The impairment test requires allocating goodwill and other assets and liabilities to reporting units. As of December 31, 2014 and 2013, the Company had only one reporting unit. To assess impairment, the Company has the option to qualitatively assess if it is more likely than not that the fair value of the reporting unit is less than the book value. Absent a qualitative assessment, or, through the qualitative assessment, if the Company determines it is more likely than not that the fair value of the reporting unit is less than the book value, a quantitative assessment is prepared to calculate the fair market value of the reporting unit. If it is determined that the fair value of the reporting unit is less than the book value, the recorded goodwill is impaired to its implied fair value with a charge to operating expenses. For the years ended December 31, 2014 and 2013, no impairment charge occurred.
	Deferred Equity Issuance Costs
	Deferred equity issuance costs consist principally of fees incurred through the consolidated balance sheet dates that are related to an equity issuance and that will be charged to stockholders’ equity upon the receipt of the equity proceeds or charged to expense if the equity offering is not completed. During the year ended December 31, 2014 and 2013, the Company incurred deferred equity issuance costs of approximately $0 and $265, respectively. The deferred equity issuance costs are included in other non-current assets in the consolidated balance sheets.  Additionally, these costs are reviewed periodically by management for indications of impairment. For the year ended December 31, 2014, the Company wrote off these deferred issuance costs as a result of the equity transaction not closing.
	Asset Retirement Obligations
	The Company records the fair value of obligations associated with the retirement of tangible long-lived assets in the period in which it is incurred. When the liability is initially recorded, the entity capitalizes a cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value each period, and the capitalized cost is depleted as part of the oil and natural gas property. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement. The Company’s asset retirement obligations relate to the plugging, dismantlement, removal, site reclamation and similar activities of its oil and natural gas properties.
	Asset retirement obligations are estimated at the present value of expected future net cash flows and are discounted using the Company’s credit adjusted risk free rate. The Company uses unobservable inputs in the estimation of asset retirement obligations that include, but are not limited to, costs of labor, costs of materials, profits on costs of labor and materials, the effect of inflation on estimated costs, and the discount rate. Accordingly, asset retirement obligations are considered a Level 3 measurement under ASC 820. Additionally, because of the subjectivity of assumptions and the relatively long lives of the Company’s wells, the costs to ultimately retire the Company’s wells may vary significantly from prior estimates.
	Revenue Recognition and Natural Gas Imbalances
	The Company utilizes the accrual method of accounting for natural gas and crude oil revenues, whereby revenues are recognized based on the Company’s net revenue interest in the wells.  The Company will also enter into physical contract sale agreements through its normal operations. These contracts are not considered derivative contracts by the Company in accordance with the normal purchases and normal sales provision of ASC 815-10-15.
	Gas imbalances are accounted for using the sales method.  Under this method, revenues are recognized based on actual volumes of oil and gas sold to purchasers.  However, the Company has no history of significant gas imbalances.
	Loss on turn-key contracts
	During the year ended December 31, 2013, the Company was involved in an arbitration case regarding the drilling, completion and operation of wells on behalf of third party oil and natural gas property operators. In March of 2014, the arbitrator for this case awarded a final award amount of approximately $580 to the third party oil and natural gas operator due from the Company, which is included in the accounts payable and accrued liabilities of the accompanying consolidated balance sheet at December 31, 2013. Additionally, during the year ended December 31, 2013, the Company incurred drilling, completion and operating costs under these turn-key contracts, which reimbursement was deemed to be uncollectible due to the outcome of the arbitration. These uncollectable turn-key contract expenses approximated $888 during the year ended December 31, 2013, and are reflected in the loss on turn-key contracts in the accompanying consolidated statement of operations.
	Lease Operating Expenses
	Lease operating expenses represents severance and production taxes, field personnel salaries, saltwater disposal, ad valorem taxes, repairs and maintenance, and other operating expenses. Lease operating expenses are expensed as incurred.
	Sales-Based Taxes
	The Company incurs severance tax on the sale of its production which is generated in Texas. These taxes are reported on a gross basis and are included in lease operating expenses within the accompanying consolidated statements of operations. Sales-based taxes for the years ended December 31, 2014 and 2013 were approximately $210 and $199, respectively.
	Income Taxes
	The Company complies with GAAP which requires an asset and liability approach to financial reporting for income taxes. Deferred income tax assets and liabilities are computed for differences between the financial statement and tax basis of assets and liabilities that will result in future taxable or deductible amounts, based on enacted tax laws and rates applicable to the periods in which the differences are expected to affect taxable income. Valuation allowances are established, when necessary, to reduce deferred income tax assets to the amount expected to be realized.
	The Company is required to determine whether its tax positions are more likely than not to be sustained upon examination by the applicable taxing authority, including resolution of any related appeals or litigation processes, based on the technical merits of the position. The tax benefit recognized is measured as the largest amount of benefit that has a greater than fifty percent likelihood of being realized upon ultimate settlement with the relevant taxing authority. De-recognition of a tax benefit previously recognized results in the Company recording a tax liability that reduces ending retained earnings. Based on its analysis, the Company has determined that it has not incurred any liability for unrecognized tax benefits as of December 31, 2014 and 2013.
	The Company’s conclusions may be subject to review and adjustment at a later date based on factors including, but not limited to, on-going analyses of and changes to tax laws, regulations and interpretations thereof. The Company recognizes interest and penalties related to unrecognized tax benefits in interest expense and other expenses, respectively. No interest expense or penalties have been recognized as of December 31, 2014 and 2013 and for the years then ended.
	The Company files an income tax return in the U.S. federal jurisdiction, and may file income tax returns in various U.S. states and foreign jurisdictions. Generally, the Company is subject to income tax examinations by major taxing authorities since 2011.
	The Company may be subject to potential examination by U.S. federal, U.S. states or foreign jurisdiction authorities in the areas of income taxes. These potential examinations may include questioning the timing and amount of deductions, the nexus of income among various tax jurisdictions and compliance with U.S. federal, U.S. state and foreign tax laws. The Company’s management does not expect that the total amount of unrecognized tax benefits will materially change over the next twelve months.
	Net Loss Per Common Share
	Basic net loss per common share is computed by dividing the net loss attributable to shareholders by the weighted average number of common shares outstanding during the period. Diluted net income per common share is calculated in the same manner, but also considers the impact to net loss and common shares for the potential dilution from convertible preferred stock and warrants. For the years ended December 31, 2014 and 2013 there were 4,898,940 and 1,374,500, respectively, dilutive shares that were not included in the diluted weighted average common shares as the Company had a net loss for the period.
	Stock-Based Compensation
	The Company accounts for stock-based compensation in accordance with ASC 718, Compensation – Stock Compensation. The standard requires the measurement and recognition of compensation expense in the Company’s consolidated statements of operations for all share-based payment awards made to the Company’s employees, directors and consultants including employee stock options, non-vested equity stock and equity stock units, and employee stock purchase grants. Stock-based compensation expense is measured at the grant date, based on the estimated fair value of the award, reduced by an estimate of the annualized rate of expected forfeitures, and is recognized as an expense over the employees’ expected requisite service period, generally using the straight-line method. In addition, ASC 718 requires the benefits of tax deductions in excess of recognized compensation expense to be reported as a financing cash flow, rather than as an operating cash flow as prescribed under previous accounting rules.
	The Company’s forfeiture rate represents the historical rate at which the Company’s stock-based awards were surrendered prior to vesting. ASC 718 requires forfeitures to be estimated at the time of grant and revised on a cumulative basis, if necessary, in subsequent periods if actual forfeitures differ from those estimates.
	During the year ended December 31, 2014 and 2013, the Company incurred a stock based compensation expense of approximately $669 and $270, respectively, related to stock grant issuances and is included in the accompanying consolidated statement of operations in general and administrative expenses.
	Use of Estimates
	The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Additionally, the Company’s estimates of oil and natural gas reserves are, by necessity, projections based on geologic and engineering data, and there are uncertainties inherent in the interpretation of such data as well as the projection of future rates of production and the timing of development expenditures. Reserve engineering is a subjective process of estimating underground accumulations of natural gas and oil that are difficult to measure. The accuracy of any reserve estimate is a function of the quality of available data, engineering and geological interpretation and judgment. Estimates of economically recoverable natural gas and oil reserves and future net cash flows necessarily depend upon a number of variable factors and assumptions, such as historical production from the area compared with production from other producing areas, the assumed effect of regulations by governmental agencies, and assumptions governing future natural gas and oil prices, future operating costs, severance taxes, development costs and workover costs, all of which may in fact vary considerably from actual results. The future drilling costs associated with reserves assigned to proved undeveloped locations may ultimately increase to the extent that these reserves are later determined to be uneconomic. For these reasons, estimates of the economically recoverable quantities of expected natural gas and oil attributable to any particular group of properties, classifications of such reserves based on risk of recovery, and estimates of the future net cash flows may vary substantially. Any significant variance in the assumptions could materially affect the estimated quantity of the reserves, which could affect the carrying value of the Company’s oil and natural gas properties and/or the rate of depletion related to the oil and natural gas properties.
Recent Accounting Pronouncements
In January 2015, the Financial Accounting Standards Board (“FASB”) issued ASU 2015-01, "Income Statement - Extraordinary and Unusual Items (Subtopic 225-20)," which eliminates the concept of extraordinary items in US GAAP. An entity is required to apply ASU 2015-01 for annual and interim reporting periods beginning after December 15, 2015. An entity may apply ASU 2015-01 prospectively or retrospectively for all periods presented in the financial statements. The Company does not expect the impact of its pending adoption of this guidance will have a material effect on its consolidated financial statements.
In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” which provides a comprehensive revenue recognition standard for contracts with customers that supersedes current revenue recognition guidance including industry specific guidance. An entity is required to apply ASU 2014-09 for annual and interim reporting periods beginning after December 15, 2016. An entity can apply ASU 2014-09 using either a full retrospective method, meaning the standard is applied to all of the periods presented, or a modified retrospective method, meaning the cumulative effect of initially applying the standard is recognized in the most current period presented in the financial statements. The Company is evaluating the impact that this new guidance will have on its consolidated financial statements.

Note_4_Fair_Value_Measurements

Note 4 - Fair Value Measurements	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value Disclosures [Text Block]	4	Fair value measurements
	The following table presents information about the Company’s assets and liabilities measured at fair value as of December 31, 2014:
			Level 1		Level 2		Level 3		Balance as of
									December 31,
									2014
	Assets (at fair value):
	Commodity Derivatives		$	679	$	-	$	-	$	679
	Liabilities (at fair value):
	Asset retirement obligations			-		-		990		990
	Total liabilities (at fair value)		$	-	$	-	$	990	$	990
	The following table presents information about the Company’s assets and liabilities measured at fair value as of December 31, 2013:
			Level 1		Level 2		Level 3		Balance as of
									December 31,
									2013
	Assets (at fair value):
	Money market mutual fund		$	63	$	-	$	-	$	63
	Liabilities (at fair value):
	Commodity derivative liabilities		$	-	$	143	$	-	$	143
	Asset retirement obligations			-		-		959		959
	Total liabilities (at fair value)		$	-	$	143	$	959	$	1,102

Note_5_Oil_and_Natural_Gas_Pro

Note 5 - Oil and Natural Gas Properties	12 Months Ended
	Dec. 31, 2014
Oil and Gas Property [Abstract]
Oil and Gas Properties [Text Block]	5	Oil and natural gas properties
	The following tables present a summary of the Company’s oil and natural gas properties at December 31, 2014 and 2013:
			2014			2013
	Proved-developed producing properties		$	6,663		$	6,424
	Proved-developed non producing properties			9,534			9,534
	Proved-undeveloped properties			9,972			9,972
	Less: Accumulated depletion			(2,759	)		(2,330	)
	Total oil and natural gas properties, net of accumulated depletion		$	23,410		$	23,600
	Effective May 2013 through August 2013, TransCoastal entered into purchase agreements with several entities and individuals to acquire various oil and natural gas properties, which include working interests ranging from 0.247% to 100%, and net revenue interests ranging from 0.186% to 81.25% in multiple counties of Texas and Louisiana, for a total consideration of approximately $859. The purchase price was derived based on the cash consideration paid directly by the Company and debt financing, along with the issuance of common stock and warrants at fair value. The following table presents a summary of the fair value of assets and liabilities acquired in accordance with ASC 805-10, Business Combinations:
	Fair value of assets acquired and liabilities assumed
	Proved-developed producing properties		$	876
	Asset retirement obligation			(17	)
	Total fair value of assets acquired and liabilities assumed, net		$	859
	Consideration transferred
	Cash consideration paid directly by the Company		$	140
	Cash consideration paid through debt financing			322
	Stock to be issued at fair value			397
	Total consideration paid		$	859

Note_6_Other_Property_and_Equi

Note 6 - Other Property and Equipment	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment Disclosure [Text Block]	6	Other property and equipment
	The following table presents a summary of the Company’s other property and equipment at December 31, 2014 and 2013:
			2014			2013
	Field equipment		$	322		$	322
	Vehicles			512			512
	Office equipment			245			245
	Buildings			130			130
	Land			14			14
	Less: Accumulated depreciation			(825	)		(753	)
	Total other property and equipment, net of accumulated depreciation		$	398		$	470

Note_7_Asset_Retirement_Obliga

Note 7 - Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation Disclosure [Text Block]	7	Asset retirement obligations
	The Company has recognized the fair value of its asset retirement obligations related to the future costs of plugging, abandonment, and remediation of oil and natural gas producing properties. The present value of the estimated asset retirement obligations has been capitalized as part of the carrying amount of the related oil and natural gas properties. The liability has been accreted to its present value as of the end of each period.  At December 31, 2014 and 2013, the Company evaluated 216 and 218 wells, and has determined a range of abandonment dates between December 2015 and December 2051. The following table represents a reconciliation of the asset retirement obligations for the years ended December 31, 2014 and 2013:
			2014		2013
	Asset retirement obligations, start of year		$	959	$	877
	Additions to asset retirement obligation			-		37
	Accretion of discount			31		45
	Asset retirement obligations, end of year		$	990	$	959

Note_8_Notes_Payable

Note 8 - Notes Payable	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt Disclosure [Text Block]	8	Notes payable
	On May 19, 2011, as amended from time to time through February 12, 2014, the Company entered into a loan agreement (the “Agreement”) with Green Bank with an initial borrowing base of $15,000 and amended to $16,950 on February 12, 2014. The Agreement bears interest at the prime rate minus 0.5%, but not less than 4.5%. Interest payments are due monthly with all principal and any unpaid interest being due on June 1, 2015. The interest rate was 4.5% at December 31, 2014 and 2013. Additionally, in accordance with the Agreement, for the period from March 1, 2012 through September 30, 2012, monthly borrowing base reductions of $125 occurred automatically on the first day of each month. Effective October 1, 2012, the monthly borrowing base reduction increased to $150 through January 15, 2013. The monthly borrowing base reductions were amended to $0 on February 11, 2013. On February 12, 2014, the monthly borrowing base reductions were amended to $125 payable on the first of each month for the period of March 1, 2014 through May 1, 2015.
	The Agreement is collateralized by essentially all of the oil and natural gas related assets of the Company, contains personal guarantees from the principal officers, and requires compliance with certain financials covenants including, among others: (1) a requirement to maintain a current ratio of not less than 1.0 to 1.0; (2) a maximum permitted ratio of total liabilities to tangible net worth of not more than 2.0 to 1.0; and (3) a requirement to maintain a ratio of EBITDAX, as defined by the Agreement, to interest expense of not less than (a) 3.00 to 1.00 for all fiscal quarters prior to December 31, 2011, (b) 3.25 to 1.00 for the fiscal quarter ending March 31, 2012, and (c) 3.50 to 1.00 for all fiscal quarters ending on or after June 30, 2012. As of December 31, 2013, the Company was not in compliance with its current ratio. Accordingly, the balance as of December 31, 2013 is classified as current. The Company was in compliance with all financial covenants as of December 31, 2014 by way of a forbearance agreement executed on February 20, 2015 and filed with the SEC on a Form 8-K. The forbearance applies to all existing and anticipated events of default in regards to the loan until April 6, 2015.
	As of December 31, 2014 and 2013, the Company had an outstanding principal balance due to Green Bank of approximately $15,750 and $17,500, respectively. As of December 31, 2014 and 2013, the current maturities of the outstanding principal balance were approximately $15,750 and $17,500, respectively.
	Additionally, on October 21, 2013, the Company entered into a vehicle loan agreement (“Car Note”) with Western Equipment Finance, Inc. for a total borrowing base of $74. The Car Note bears interest at an approximate rate of 9%. Interest and principal payments are due monthly with any unpaid principal and interest due on August 18, 2018. As of December 31, 2014 and 2013, the Company had an outstanding principal balance due to Western Equipment Finance, Inc. of approximately $56 and $68, respectively. As of December 31, 2014 and 2013, the current maturities of the outstanding principal balance were approximately $12.
	On June 30, 2014, the Company entered into a loan agreement with an individual, Dalton Lott, a related party. The principal amount of the debt consists of $1,500,000 with 5.5% annual interest. The note consists of interest only payments from January 1 thru June 1, 2015. Beginning July 1, 2015, interest and principal payments are due every month for 60 months. Dalton Lott is the father in law of the Company’s Chief Executive Officer, Stuart Hagler.
	Aggregate future maturities of the notes payable are as follows as of December 31, 2014:
	2015		$	15,828,959
	2016			285,041
	2017			300,368
	2018			316,559
	2019			322,557
	Thereafter			252,054

Note_9_Deferred_Income_Taxes

Note 9 - Deferred Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Tax Disclosure [Text Block]	9	Deferred income taxes
	For the years ended December 31, 2014 and 2013, the Company estimated no current or deferred tax provisions. A reconciliation of income tax expense (benefit) computed by applying the U.S. federal statutory income tax rate and the reported effective tax rate on income for the years ended December 31, 2014 and 2013 are as follows:
			2014			2013
	Income tax provision calculated using the federal statutory income tax rate		$	(576	)	$	(1,378	)
	Permanent differences and other			(657	)		2
	Oil and gas properties			10			-
	Asset retirement obligation			20			-
	Change in valuation allowance			(1,203	)		1,376
	Total income tax expense		$	-		$	-
	Deferred tax assets are determined based on the difference between financial statement and tax bases using enacted tax rates in effect for the year in which the differences are expected to reverse. The components of the deferred taxes as of December 31, 2014 and 2013 are as follows:
			2014			2013
	Deferred tax assets
	Federal net operating loss carryforward		$	4,141		$	3,056
	Asset retirement obligations			337			326
	Total deferred tax assets			4,478			3,382
	Deferred tax liabilities
	Depletion and Depreciation			223			242
	Net deferred tax asset, before valuation allowance			4,255			3,140
	Valuation allowance			(4,255	)		(3,140	)
	Net deferred tax asset
	As of December 31, 2014 and 2013, the Company had net operating loss (“NOL”) carryforwards of approximately $12,179 and $8,686, respectively, which can be utilized in future years. These NOLs, if not used, will expire between 2026 and 2034. A valuation allowance has been established for the full amount of the tax asset since it is more likely than not that the deferred tax asset will not be realized.

Note_10_Shareholders_Equity

Note 10 - Shareholders' Equity	12 Months Ended
	Dec. 31, 2014
Stockholders' Equity Note [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	10	Shareholders’ equity
	Reverse Recapitalization
	Claimsnet acquired TransCoastal under the Acquisition Agreement, dated March 18, 2013, (as amended by the Amended Acquisition Agreement, dated April 24, 2013), through the issuance of shares of Claimsnet’s convertible preferred stock. Pursuant to the Amended Acquisition Agreement, on June 27, 2013 the Company placed all of the assets and liabilities constituting the current non-oil and gas assets of the Company into a separate wholly-owned subsidiary of the Company, ANC Holdings. ANC Holdings was then sold to certain affiliated debt holders of the Company, in consideration for cancelling the indebtedness owed. Additionally, on July 30, 2013 the Board of Directors, after receiving approval of the corporate action by FINRA, authorized the completion of the two hundred to one (200 to 1) reverse stock split of the issued and outstanding Common Stock, as may be adjusted (the “ Reverse Stock Split”), that reduced the outstanding shares of Common Stock from 35,644,696 to approximately 178,224 shares (recognizing that any resulting fractional shares will be rounded up to result in a maximum aggregate 178,250 post-split shares) and changed the name of the Company to TransCoastal Corporation. On July 30, 2013 the Board of Directors of the Company also authorized the issuance of Common Stock share certificates of the Company to all the Series F Preferred Stockholders converting the Company's Series F preferred shares into Common Stock of the Company.
	Stock Issuances
	During the year ended December 31, 2014 and 2013, the Company issued 0 and 206,250 shares, respectively, of Series A convertible preferred stock at 8%, payable annually, for $0 and $679, respectively. The Series A preferred stock may be converted any time after the first year at the request of the shareholder or the Company into two (2) shares of common stock of TransCoastal and one (1) warrant that will allow the holder, for a period of three years from the date of issue, to acquire one additional share of TransCoastal common stock for each warrant at a purchase price of $3.50 per share. The Series A preferred stock issued in 2013 resulted in a beneficial conversion feature at the date of issuance. As a result, a constructive dividend on the Series A preferred stock of approximately $266 is reflected in the accompanying consolidated statements of changes in shareholders’ equity. All of the Series A preferred shares were converted into common stock during the year ended December 31, 2013. Prior to conversion, the Company paid approximately $39 of cash dividends to the Series A preferred shareholders.
	During the year ended December 31, 2014 and 2013, the Company issued 603,000 and 687,250 shares, respectively, of Series G convertible preferred stock at 8%, payable annually. The preferred stock may be converted any time after the first year at the request of the shareholder or the Company into two (2) shares of common stock of TransCoastal and two (2) warrants that will allow the holder, for a period of two years from the date of issue, to acquire one additional share of TransCoastal common stock for each warrant at a purchase price of $3.75 per share. The Series G preferred stock issued in 2013 resulted in a beneficial conversion feature at the date of issuance. As a result, a constructive dividend on the Series G preferred stock of approximately $1,756 is reflected in the accompanying consolidated statement of changes in shareholders’ equity. All of the Series G preferred shares were converted into common stock during the year ended December 31, 2014. In 2014 prior to conversion, the Company paid approximately $103 of cash dividends to the Series G preferred shareholders.
	During the year ended December 31, 2013, the Company entered into an investment agreement with a third party which allows the Company to put common shares to the third party for an aggregate purchase price up to $5,000. The purchase price of the third party would be equal to 75% of the lowest daily closing bid price of the Company’s common stock during the pricing period. The pricing period is represented by the five trading days immediately following the date on which the Company provides written notice to the third party of its requested investment. In order to facilitate the execution of this investment agreement, the Company paid the third party $15 in cash and issued 256,578 shares of its common stock valued at $250. As of December 31, 2013, the total consideration of $265 is included in other non-current assets in the accompanying consolidated balance sheets.
	During the year ended December 31, 2014 the Company issued 1,125,000 shares of Series H convertible preferred stock at 9%, payable semiannually. The preferred stock may be converted any time after the first year at the request of the shareholder or any time after three years at the request of the Company. The preferred stock converts into two (2) shares of common stock of TransCoastal and two (2) warrants that will allow the holder, for a period of two years from the date of issue, to acquire one additional share of TransCoastal common stock for each warrant at a purchase price of $3.50 per share. During 2014 the Company accrued $47 in dividends on Series H preferred stock.
	Stock Issuances for Services
	During the year ended December 31, 2013, the Company issued 207,467 common shares to certain employees for services to the Company. The Company valued those services at approximately $270.
	During the year ended December 31, 2014, the Company issued 2,139,162 shares for stock based compensation to directors and officers of the Company. The Company valued that compensation at $669.
	Stock Issued as of December 31, 2014 and 2013
	At December 31, 2014 and 2013, the authorized capital stock of the Company consisted of 250,000,000 shares of voting common stock with a par value of $0.001 per share and 25,000,000 shares of preferred stock with a par value of $0.001 per share. As of December 31, 2014 and 2013, there were 29,334,264 and 22,453,773, respectively, common shares issued and outstanding, 0 and 687,500, respectively, Series G preferred shares issued and outstanding, and 1,125,000 and 0, respectively, Series H preferred shares issued and outstanding. Additionally, at December 31, 2014 and 2013, there were 735,845 and 265,625, respectively, common shares to be issued and 393,471 and 165,105, respectively, Series F preferred shares to be issued. During the year ended December 31, 2014, 825,829 shares were issued to settle 1,653 of stock to be issued liability. As of December 31, 2014 and 2013, the total long-term liability for stock to be issued was approximately $845 and $2,496, respectively, which is included in the accompanying consolidated balance sheets.

Note_11_Derivative_Contracts_a

Note 11 - Derivative Contracts, at Fair Value	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities Disclosure [Text Block]	11	Derivative contracts, at fair value
	In the normal course of business, the Company utilizes derivative contracts in connection with its oil and natural gas operations. Derivative contracts are subject to additional risks that can result in additional losses. The Company’s derivative activities and exposure to derivative contracts are classified by the following primary underlying risk: commodity price. In addition to its primary underlying risk, the Company is also subject to additional counterparty risk due to inability of its counterparties to meet the terms of their contracts.
	Options
	The Company is subject to commodity price risk in the normal course of pursuing its investment objectives. The Company may enter into options to speculate on the price movements of the commodity underlying the option or for use as an economic hedge against oil and natural gas production.
	Option contracts purchased give the Company the right, but not the obligation, to buy or sell within a limited time, a commodity at a contracted price that may also be settled in cash, based on differentials between specified indices or prices. For some OTC options, the Company may be exposed to counterparty risk from the potential that a seller of an option contract does not sell or purchase the underlying asset as agreed under the terms of the option contract. The maximum risk of loss from counterparty risk to the Company is the fair value of the contracts and the premiums paid to purchase its open option contracts. In these instances, the Company considers the credit risk of the intermediary counterparty to its option transactions in evaluating potential credit risk.
	Swap Contracts
	Generally, a swap contract is an agreement that obligates two parties to exchange a series of cash flows at specified intervals based upon or calculated by reference to changes in specified prices or rates for a specified notional amount of the underlying assets. The payment flows are usually netted against each other, with the difference being paid by one party to the other. During the term of the swap contracts, changes in value are recognized as unrealized gains or losses by marking the contracts at fair value. Additionally, the Company records a realized gain (loss) when a swap contract is terminated and when periodic payments are received or made at the end of each measurement period. The fair value of open swaps reported in the balance sheet may differ from that which would be realized in the event the Company terminated its position in the contracts. Risks may arise as a result of the failure of the counterparty to the swap contract to comply with the terms of the swap contract.
	The loss incurred by the failure of a counterparty is generally limited to the aggregate fair value of swap contracts in an unrealized gain position as well as any collateral posted with the counterparty. The risk is mitigated by having a master netting arrangement between the Company and the counterparty and by the posting of collateral by the counterparty to the Company to cover the Company’s exposure to the counterparty. Therefore, the Company considers the creditworthiness of each counterparty to a swap contract in evaluating potential credit risk.
	Underlying Exposure
	At December 31, 2014, the volume of the Company’s derivative activities based on their notional amounts and number of contracts, categorized by primary underlying risk, are as follows:
			Long Exposure						Short Exposure
	Primary underlying risk		Notional			Number of			Notional			Number of
			Amounts(a)			Contracts(b)			Amounts(a)			Contracts(b)
	Commodity price
	Swap		$	-					$	1,064			6
	Options			384			6			1,002			6
			$	384			6		$	2,066			12
		(a)	Notional amounts presented for contracts are based on the fair value of the underlying commodity as if the contracts were exercised at December 31, 2014.
		(b)	Number of contracts is presented in whole numbers.
	At December 31, 2013, the volume of the Company’s derivative activities based on their notional amounts and number of contracts, categorized by primary underlying risk, are as follows:
			Long Exposure						Short Exposure
	Primary underlying risk		Notional			Number of			Notional			Number of
			Amounts(c)			Contracts(d)			Amounts(c)			Contracts(d)
	Commodity price
	Swap		$	-			-		$	3,111			4
	Options			354			1			266			1
			$	354			1		$	3,377			5
		(c)	Notional amounts presented for contracts are based on the fair value of the underlying commodity as if the contracts were exercised at December 31, 2013.
		(d)	Number of contracts is presented in whole numbers.
	Impact of Derivatives on the Consolidated Balance Sheets and Consolidated Statements of Operations
	The following table identifies the fair value amounts of derivative instruments included in the accompanying consolidated balance sheet as derivative assets and derivative liabilities, categorized by primary underlying risk, at December 31, 2014. Balances are presented on a gross basis, prior to the application of the impact of counterparty and collateral netting.
			Derivative Assets			Derivative Liabilities			Amount of gain (loss)
	Primary underlying risk
	Commodity price
	Swaps		$	406		$	-		$	406
	Options			682			(409	)		273
	Gross total			1,088			(409	)		679
	Less: Master netting arrangements			1			(1	)
	Total		$	1,089		$	(410	)	$	679
	The following table identifies the fair value amounts of derivative instruments included in the accompanying consolidated balance sheet as derivative assets and derivative liabilities, categorized by primary underlying risk, at December 31, 2013.
	Balances are presented on a gross basis, prior to the application of the impact of counterparty and collateral netting.
			Derivative Assets			Derivative Liabilities			Amount of loss
	Primary underlying risk
	Commodity price
	Swaps		$	-		$	(135	)	$	(261	)
	Options			1			(9	)		(8	)
	Gross total			1			(144	)		(269	)
	Less: Master netting arrangements			1			(1	)		-
	Total		$	-		$	(143	)	$	(269	)
	The following table identifies the net gain and (loss) amounts included in the accompanying consolidated statement of operations as derivative losses for the year ended December 31, 2014.
			Realized gain (loss)			Unrealized gain (loss)			Total
	Primary underlying risk
	Commodity price
	Swaps		$	540		$	(115	)	$	425
	Options			281			(25	)		256
	Total		$	821		$	(140	)	$	681
	The following table identifies the net gain and (loss) amounts included in the accompanying consolidated statement of operations as derivative losses for the year ended December 31, 2013.
			Realized loss			Unrealized loss			Total
	Primary underlying risk
	Commodity price
	Swaps		$	(104	)	$	(157	)	$	(261	)
	Options			-			(8	)		(8	)
	Total		$	(104	)	$	(165	)	$	(269	)

Note_12_Related_Party_Transact

Note 12 - Related Party Transactions	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions Disclosure [Text Block]	12	Related party transactions
	On June 30, 2014, the Company entered into a loan agreement with an individual, Dalton Lott, a related party. The principal amount of the debt consists of $1,500,000 with 5.5% annual interest. The note consists of interest only payments from January 1 thru June 1, 2015. Beginning July 1, 2015, interest and principal payments are due every month for 60 months. Dalton Lott is the father in law of the Company’s Chief Executive Officer, Stuart Hagler.

Note_13_Commitments_and_Contin

Note 13 - Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies Disclosure [Text Block]	13	Commitments and contingencies
	Oil and Natural Gas Regulations
	The Company is subject to various possible contingencies that arise primarily from interpretation of federal and state laws and regulations affecting the oil and natural gas industry. Such contingencies include differing interpretations as to the prices at which oil and natural gas sales may be made, the prices at which royalty owners may be paid for production from their leases, environmental issues and other matters. Although management believes that it has complied with the various laws and regulations, administrative rulings and interpretations thereof, adjustments could be required as new interpretations and regulations are issued. In addition, environmental matters are subject to regulation by various federal and state agencies.
	Legal Proceedings
	The Company is subject to various legal proceedings and claims that arise in the ordinary course of business. During the year ended December 31, 2013, the Company was involved in an arbitration case regarding the drilling, completion and operation of wells on behalf of third party oil and natural gas property operators. In March 2014, the arbitrator for this case awarded a final award amount of approximately $580 to the third party oil and natural gas operator due from the Company, which is included in the accounts payable and accrued liabilities of the accompanying consolidated balance sheet at December 31, 2013. In January 2015, the Company settled outstanding litigation with a third party. The settlement calls for the Company to make a payment of $15 on January 6, 2015 and subsequent payments of $5 due on the first of each month from February through November 2015. The total balance of the settlement has been expensed and accrued.
	Lease Commitments
	The Company leases its primary office space under an operating lease which expires in 2015. Lease expense was approximately $182 and $193, respectively, for the years ended December 31, 2014 and 2013. Aggregate future minimum annual rental payments are $30.

Note_14_Risk_Concentrations

Note 14 - Risk Concentrations	12 Months Ended
	Dec. 31, 2014
Risks and Uncertainties [Abstract]
Concentration Risk Disclosure [Text Block]	14	Risk concentrations
	For the years ended December 31, 2014 and 2013, revenues from the Company’s 36 and 44 producing leases, respectively, ranged from approximately 0.1% to 31.1% and 0.1% to 11.8%, respectively, of total oil, natural gas, and related product sales. These 36 and 44, respectively, leases are located in various counties of Texas.
	For the years ended December 31, 2014 and 2013, the oil and natural gas produced by the Company is sold and marketed to 9 and 11 purchasers, respectively. Accordingly, the Company’s entire oil and natural gas sales receivable balance at December 31, 2014 and 2013 was comprised of amounts due from its 9 and 11, respectively, purchasers. Oil and natural gas sales receivable are included in the accounts receivable, net on the accompanying consolidated balance sheets.

Note_15_Subsequent_Event

Note 15 - Subsequent Event	12 Months Ended
	Dec. 31, 2014
Subsequent Events [Abstract]
Subsequent Events [Text Block]	15	Subsequent Event
	TransCoastal Corporation has entered into a Forbearance Agreement with Melody Business Finance, LLC (the “New Lender”) pursuant to the New Lender assuming the Loan Agreement dated May 2011 with Green Bank N.A. The principal amount of the note is $15,750,000 with a maturity date of June 1, 2015. The New Lender has agreed to enter into a Forbearance Agreement regarding all “Existing Events of Default” as well as agreed upon “Anticipated Events of Default” pursuant to the default provisions of the existing Loan Agreement. The forbearance agreement was filed with the SEC on a Form 8-K on February 20, 2015.

Accounting_Policies_by_Policy_

Accounting Policies, by Policy (Policies)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Consolidation, Policy [Policy Text Block]	Principles of Consolidation
	The accompanying consolidated financial statements include the accounts of TransCoastal and its wholly owned subsidiary, CTO. All intercompany transactions and balances have been eliminated in consolidation.
Fair Value Measurement, Policy [Policy Text Block]	Fair Value Measurements
	The Company has adopted and follows ASC 820, Fair Value Measurements and Disclosures, for measurement and disclosures about fair value of its financial instruments.  ASC 820 establishes a framework for measuring fair value in GAAP, and expands disclosures about fair value measurements. To increase consistency and comparability in fair value measurements and related disclosures, ASC 820 establishes a fair value hierarchy which prioritizes the inputs to valuation techniques used to measure fair value into three (3) broad levels.  The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities and the lowest priority to unobservable inputs.  The three (3) levels of fair value hierarchy defined by ASC 820 are:
	Level 1 — Inputs are unadjusted, quoted prices in active markets for identical assets or liabilities at the measurement date.
	Level 2 — Inputs (other than quoted market prices included in Level 1) are either directly or indirectly observable for the asset or liability through correlation with market data at the measurement date and for the duration of the instrument’s anticipated life.
	Level 3 — Inputs reflect management’s best estimate of what market participants would use in pricing the asset or liability at the measurement date. Consideration is given to the risk inherent in the valuation technique and the risk inherent in the inputs to the model. Valuation of instruments includes unobservable inputs to the valuation methodology that are significant to the measurement of fair value of assets or liabilities.
	As defined by ASC 820, the fair value of a financial instrument is the amount at which the instrument could be exchanged in a current transaction between willing parties, other than in a forced or liquidation sale, which was further clarified as the price that would be received to sell an asset or paid to transfer a liability (“an exit price”) in an orderly transaction between market participants at the measurement date.  The carrying amounts of the Company’s financial assets and liabilities, such as cash and cash equivalents, oil and natural gas sales receivable, and accounts payable and accrued liabilities, approximate their fair values because of the short maturity of these instruments.
Cash and Cash Equivalents, Policy [Policy Text Block]	Cash and Cash Equivalents
	The Company considers all highly-liquid debt instruments with original maturities of three months or less to be cash equivalents. As of December 31, 2014 and 2013, the Company held approximately $127 and $63, respectively, in cash equivalents.
	The Company maintains its cash balances in financial institutions which are insured by the Federal Deposit Insurance Corporation (“FDIC”). The interest bearing cash accounts maintain FDIC coverage of up to $250 per institution. As of December 31, 2014 and 2013, the Company had $0 and $44, respectively, in excess of its FDIC coverage.
Receivables, Policy [Policy Text Block]	Accounts Receivable
	Accounts receivable is comprised of billings for services as the operator on certain wells, that TransCoastal has no working interest in, and accrued natural gas and crude oil sales. The Company performs ongoing credit evaluations of its customers’ and extends credit to virtually all of its customers. Credit losses to date have not been significant and have been within management’s expectations.  In the event of complete non-performance by the Company’s customers, the maximum exposure to the Company is the outstanding accounts receivable, net balance at the date of non-performance. The amounts billed to third parties for services as the operator have rights of offset against revenues generated from the sale of oil and gas commodities. For the years ended December 31, 2014 and 2013, the Company had no bad debt expense or allowance.
Derivatives, Policy [Policy Text Block]	Derivative Activities
	The Company utilized oil and natural gas derivative contracts to mitigate its exposure to commodity price risk associated with its future oil and natural gas production. These derivative contracts have historically consisted of options, in the form of price floors or collars. The Company’s derivative financial instruments are recorded on the consolidated balance sheets as either an asset or a liability measured at fair value. The Company does not apply hedge accounting to its oil and natural gas derivative contracts and accordingly the changes in the fair value of these instruments are recognized in the consolidated statements of operations in the period of change.
	The Company’s derivative instruments are issued to manage the price risk attributable to our expected natural gas and oil production. While there is risk that the financial benefit of rising natural gas and oil prices may not be captured, Company management believes the benefits of stable and predictable cash flow are more important. Every unsettled derivative instrument is recorded on the accompanying consolidated balance sheets as either an asset or a liability measured at its fair value.
	Changes in a derivative’s fair value are recognized in earnings unless specific hedge accounting criteria are met. Cash flows from natural gas and oil derivative contract settlements are reflected in operating activities in the accompanying consolidated statements of cash flows.
	Realized and unrealized gains and losses on derivatives are accounted for using the mark-to-market accounting method. We recognize all unrealized and realized gains and losses related to these contracts in each period in derivative gains or (losses) in the accompanying consolidated statements of operations.
Oil and Gas Properties Policy [Policy Text Block]	Oil and Gas Natural Gas Properties
	The Company uses the full-cost method of accounting for its oil and natural gas producing activities as further defined under ASC 932, Extractive Activities - Oil and natural gas. Under these provisions, all costs incurred for both successful and unsuccessful exploration and development activities, including salaries, benefits and other internal costs directly identified with these activities, and oil and natural gas property acquisitions are capitalized. All costs related to production, general corporate overhead or similar activities are expensed as incurred.
	Proved properties are amortized using the units of production method (“UOP”). The UOP calculation, in its simplest terms, multiplies the percentage of estimated proved reserves produced at year end by the cost of those reserves.
	The amortization base in the UOP calculation includes the sum of proved property, net of accumulated depreciation, depletion and amortization (“DD&A”), estimated future development costs (future costs to access and develop reserves) and asset retirement costs that are not already included in oil and natural gas property, less related salvage value.
	The cost of unproved properties and properties under development are excluded from the amortization calculation until it is determined whether or not proved reserves can be assigned to such properties or until development projects are placed in service. Geological and geophysical costs not associated with specific properties are recorded to proved properties. Unproved properties and properties under development are reviewed for impairment at least quarterly. In countries where proved reserves exist, exploratory drilling costs associated with dry holes are transferred to proved properties immediately upon determination that a well is dry and amortized accordingly. As of December 31, 2014 and 2013, no unproved properties or properties under development were included in the oil and natural gas properties of the accompanying consolidated financial statements.
	Proceeds from the sale or disposition of oil and natural gas properties are accounted for as a reduction to capitalized costs unless a significant portion (greater than 25 percent) of the Company’s reserve quantities in a particular country are sold, in which case a gain or loss is recognized in income. For the years ended December 31, 2014 and 2013, no gain or loss from the sale or disposition of oil and natural gas properties occurred.
	Under the full-cost method of accounting, the net book value of oil and natural gas properties, less related deferred income taxes, may not exceed a calculated “ceiling.” The ceiling limitation is the estimated after-tax future net cash flows from proved oil and natural gas reserves, discounted at 10 percent per annum based on industry standards and adjusted for cash flow hedges. Estimated future net cash flows exclude future cash outflows associated with settling accrued asset retirement obligations. Any excess of the net book value of proved oil and gas properties, less related deferred income taxes, over the ceiling is charged to expense and reflected as additional DD&A in the accompanying consolidated statements of operations. For the years ended December 31, 2014 and 2013, no impairment charge occurred.
	During the years ended December 31, 2014 and 2013, the Company determined $0 and $31, respectively, of interest costs were incurred during the development period of our wells, which is reflected as an increase to the Company’s full-cost pool in the accompanying consolidated balance sheets.
Property, Plant and Equipment, Policy [Policy Text Block]	Other Property and Equipment
	Other property and equipment, which includes buildings, field equipment, vehicles, and office equipment, is stated at cost less accumulated depreciation. Depreciation is computed using the straight-line method over the estimated useful lives of the assets. Vehicles and office equipment are generally depreciated over a useful life of five or six years, field equipment is generally depreciated over a useful life of ten years and buildings are generally depreciated over a useful life of twenty years.
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block]	Impairment of Long-Lived Assets
	The Company assesses the impairment of long-lived assets when circumstances indicate that the carrying value may not be recoverable. The Company determines if impairment has occurred through adverse changes. When it is determined that the estimated future net cash flows of an asset will not be sufficient to recover its carrying amount, an impairment loss must be recorded to reduce the carrying amount to its estimated fair value. For the years ended December 31, 2014 and 2013, no circumstances indicated an unrecoverable carrying value of the long-lived assets.
Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]	Goodwill
	Goodwill was generated as part of the CTO acquisition during the year ended December 31, 2011 and represents the excess of the purchase price over the estimated fair value of the net assets acquired in the acquisition. Goodwill is not amortized; rather, it is tested for impairment annually and when events or changes in circumstances indicate that fair value of a reporting unit with goodwill has been reduced below carrying value. The impairment test requires allocating goodwill and other assets and liabilities to reporting units. As of December 31, 2014 and 2013, the Company had only one reporting unit. To assess impairment, the Company has the option to qualitatively assess if it is more likely than not that the fair value of the reporting unit is less than the book value. Absent a qualitative assessment, or, through the qualitative assessment, if the Company determines it is more likely than not that the fair value of the reporting unit is less than the book value, a quantitative assessment is prepared to calculate the fair market value of the reporting unit. If it is determined that the fair value of the reporting unit is less than the book value, the recorded goodwill is impaired to its implied fair value with a charge to operating expenses. For the years ended December 31, 2014 and 2013, no impairment charge occurred.
Deferred Charges, Policy [Policy Text Block]	Deferred Equity Issuance Costs
	Deferred equity issuance costs consist principally of fees incurred through the consolidated balance sheet dates that are related to an equity issuance and that will be charged to stockholders’ equity upon the receipt of the equity proceeds or charged to expense if the equity offering is not completed. During the year ended December 31, 2014 and 2013, the Company incurred deferred equity issuance costs of approximately $0 and $265, respectively. The deferred equity issuance costs are included in other non-current assets in the consolidated balance sheets.  Additionally, these costs are reviewed periodically by management for indications of impairment. For the year ended December 31, 2014, the Company wrote off these deferred issuance costs as a result of the equity transaction not closing.
Asset Retirement Obligations, Policy [Policy Text Block]	Asset Retirement Obligations
	The Company records the fair value of obligations associated with the retirement of tangible long-lived assets in the period in which it is incurred. When the liability is initially recorded, the entity capitalizes a cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value each period, and the capitalized cost is depleted as part of the oil and natural gas property. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement. The Company’s asset retirement obligations relate to the plugging, dismantlement, removal, site reclamation and similar activities of its oil and natural gas properties.
	Asset retirement obligations are estimated at the present value of expected future net cash flows and are discounted using the Company’s credit adjusted risk free rate. The Company uses unobservable inputs in the estimation of asset retirement obligations that include, but are not limited to, costs of labor, costs of materials, profits on costs of labor and materials, the effect of inflation on estimated costs, and the discount rate. Accordingly, asset retirement obligations are considered a Level 3 measurement under ASC 820. Additionally, because of the subjectivity of assumptions and the relatively long lives of the Company’s wells, the costs to ultimately retire the Company’s wells may vary significantly from prior estimates.
Revenue Recognition, Policy [Policy Text Block]	Revenue Recognition and Natural Gas Imbalances
	The Company utilizes the accrual method of accounting for natural gas and crude oil revenues, whereby revenues are recognized based on the Company’s net revenue interest in the wells.  The Company will also enter into physical contract sale agreements through its normal operations. These contracts are not considered derivative contracts by the Company in accordance with the normal purchases and normal sales provision of ASC 815-10-15.
	Gas imbalances are accounted for using the sales method.  Under this method, revenues are recognized based on actual volumes of oil and gas sold to purchasers.  However, the Company has no history of significant gas imbalances.
Loss on Turnkey Contracts [Policy Text Block]	Loss on turn-key contracts
	During the year ended December 31, 2013, the Company was involved in an arbitration case regarding the drilling, completion and operation of wells on behalf of third party oil and natural gas property operators. In March of 2014, the arbitrator for this case awarded a final award amount of approximately $580 to the third party oil and natural gas operator due from the Company, which is included in the accounts payable and accrued liabilities of the accompanying consolidated balance sheet at December 31, 2013. Additionally, during the year ended December 31, 2013, the Company incurred drilling, completion and operating costs under these turn-key contracts, which reimbursement was deemed to be uncollectible due to the outcome of the arbitration. These uncollectable turn-key contract expenses approximated $888 during the year ended December 31, 2013, and are reflected in the loss on turn-key contracts in the accompanying consolidated statement of operations.
Lease, Policy [Policy Text Block]	Lease Operating Expenses
	Lease operating expenses represents severance and production taxes, field personnel salaries, saltwater disposal, ad valorem taxes, repairs and maintenance, and other operating expenses. Lease operating expenses are expensed as incurred.
Sales Based Taxes [Policy Text Block]	Sales-Based Taxes
	The Company incurs severance tax on the sale of its production which is generated in Texas. These taxes are reported on a gross basis and are included in lease operating expenses within the accompanying consolidated statements of operations. Sales-based taxes for the years ended December 31, 2014 and 2013 were approximately $210 and $199, respectively.
Income Tax, Policy [Policy Text Block]	Income Taxes
	The Company complies with GAAP which requires an asset and liability approach to financial reporting for income taxes. Deferred income tax assets and liabilities are computed for differences between the financial statement and tax basis of assets and liabilities that will result in future taxable or deductible amounts, based on enacted tax laws and rates applicable to the periods in which the differences are expected to affect taxable income. Valuation allowances are established, when necessary, to reduce deferred income tax assets to the amount expected to be realized.
	The Company is required to determine whether its tax positions are more likely than not to be sustained upon examination by the applicable taxing authority, including resolution of any related appeals or litigation processes, based on the technical merits of the position. The tax benefit recognized is measured as the largest amount of benefit that has a greater than fifty percent likelihood of being realized upon ultimate settlement with the relevant taxing authority. De-recognition of a tax benefit previously recognized results in the Company recording a tax liability that reduces ending retained earnings. Based on its analysis, the Company has determined that it has not incurred any liability for unrecognized tax benefits as of December 31, 2014 and 2013.
	The Company’s conclusions may be subject to review and adjustment at a later date based on factors including, but not limited to, on-going analyses of and changes to tax laws, regulations and interpretations thereof. The Company recognizes interest and penalties related to unrecognized tax benefits in interest expense and other expenses, respectively. No interest expense or penalties have been recognized as of December 31, 2014 and 2013 and for the years then ended.
	The Company files an income tax return in the U.S. federal jurisdiction, and may file income tax returns in various U.S. states and foreign jurisdictions. Generally, the Company is subject to income tax examinations by major taxing authorities since 2011.
	The Company may be subject to potential examination by U.S. federal, U.S. states or foreign jurisdiction authorities in the areas of income taxes. These potential examinations may include questioning the timing and amount of deductions, the nexus of income among various tax jurisdictions and compliance with U.S. federal, U.S. state and foreign tax laws. The Company’s management does not expect that the total amount of unrecognized tax benefits will materially change over the next twelve months.
Earnings Per Share, Policy [Policy Text Block]	Net Loss Per Common Share
	Basic net loss per common share is computed by dividing the net loss attributable to shareholders by the weighted average number of common shares outstanding during the period. Diluted net income per common share is calculated in the same manner, but also considers the impact to net loss and common shares for the potential dilution from convertible preferred stock and warrants. For the years ended December 31, 2014 and 2013 there were 4,898,940 and 1,374,500, respectively, dilutive shares that were not included in the diluted weighted average common shares as the Company had a net loss for the period.
Share-based Compensation, Option and Incentive Plans Policy [Policy Text Block]	Stock-Based Compensation
	The Company accounts for stock-based compensation in accordance with ASC 718, Compensation – Stock Compensation. The standard requires the measurement and recognition of compensation expense in the Company’s consolidated statements of operations for all share-based payment awards made to the Company’s employees, directors and consultants including employee stock options, non-vested equity stock and equity stock units, and employee stock purchase grants. Stock-based compensation expense is measured at the grant date, based on the estimated fair value of the award, reduced by an estimate of the annualized rate of expected forfeitures, and is recognized as an expense over the employees’ expected requisite service period, generally using the straight-line method. In addition, ASC 718 requires the benefits of tax deductions in excess of recognized compensation expense to be reported as a financing cash flow, rather than as an operating cash flow as prescribed under previous accounting rules.
	The Company’s forfeiture rate represents the historical rate at which the Company’s stock-based awards were surrendered prior to vesting. ASC 718 requires forfeitures to be estimated at the time of grant and revised on a cumulative basis, if necessary, in subsequent periods if actual forfeitures differ from those estimates.
	During the year ended December 31, 2014 and 2013, the Company incurred a stock based compensation expense of approximately $669 and $270, respectively, related to stock grant issuances and is included in the accompanying consolidated statement of operations in general and administrative expenses.
Use of Estimates, Policy [Policy Text Block]	Use of Estimates
	The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
	Additionally, the Company’s estimates of oil and natural gas reserves are, by necessity, projections based on geologic and engineering data, and there are uncertainties inherent in the interpretation of such data as well as the projection of future rates of production and the timing of development expenditures. Reserve engineering is a subjective process of estimating underground accumulations of natural gas and oil that are difficult to measure. The accuracy of any reserve estimate is a function of the quality of available data, engineering and geological interpretation and judgment. Estimates of economically recoverable natural gas and oil reserves and future net cash flows necessarily depend upon a number of variable factors and assumptions, such as historical production from the area compared with production from other producing areas, the assumed effect of regulations by governmental agencies, and assumptions governing future natural gas and oil prices, future operating costs, severance taxes, development costs and workover costs, all of which may in fact vary considerably from actual results. The future drilling costs associated with reserves assigned to proved undeveloped locations may ultimately increase to the extent that these reserves are later determined to be uneconomic. For these reasons, estimates of the economically recoverable quantities of expected natural gas and oil attributable to any particular group of properties, classifications of such reserves based on risk of recovery, and estimates of the future net cash flows may vary substantially. Any significant variance in the assumptions could materially affect the estimated quantity of the reserves, which could affect the carrying value of the Company’s oil and natural gas properties and/or the rate of depletion related to the oil and natural gas properties.
New Accounting Pronouncements, Policy [Policy Text Block]	Recent Accounting Pronouncements
	In January 2015, the Financial Accounting Standards Board (“FASB”) issued ASU 2015-01, "Income Statement - Extraordinary and Unusual Items (Subtopic 225-20)," which eliminates the concept of extraordinary items in US GAAP. An entity is required to apply ASU 2015-01 for annual and interim reporting periods beginning after December 15, 2015. An entity may apply ASU 2015-01 prospectively or retrospectively for all periods presented in the financial statements. The Company does not expect the impact of its pending adoption of this guidance will have a material effect on its consolidated financial statements.
	In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” which provides a comprehensive revenue recognition standard for contracts with customers that supersedes current revenue recognition guidance including industry specific guidance. An entity is required to apply ASU 2014-09 for annual and interim reporting periods beginning after December 15, 2016. An entity can apply ASU 2014-09 using either a full retrospective method, meaning the standard is applied to all of the periods presented, or a modified retrospective method, meaning the cumulative effect of initially applying the standard is recognized in the most current period presented in the financial statements. The Company is evaluating the impact that this new guidance will have on its consolidated financial statements.

Note_4_Fair_Value_Measurements1

Note 4 - Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]		Level 1		Level 2		Level 3		Balance as of
								December 31,
								2014
	Assets (at fair value):
	Commodity Derivatives	$	679	$	-	$	-	$	679
	Liabilities (at fair value):
	Asset retirement obligations		-		-		990		990
	Total liabilities (at fair value)	$	-	$	-	$	990	$	990
		Level 1		Level 2		Level 3		Balance as of
								December 31,
								2013
	Assets (at fair value):
	Money market mutual fund	$	63	$	-	$	-	$	63
	Liabilities (at fair value):
	Commodity derivative liabilities	$	-	$	143	$	-	$	143
	Asset retirement obligations		-		-		959		959
	Total liabilities (at fair value)	$	-	$	143	$	959	$	1,102

Note_5_Oil_and_Natural_Gas_Pro1

Note 5 - Oil and Natural Gas Properties (Tables)	12 Months Ended
	Dec. 31, 2014
Oil and Gas Property [Abstract]
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]		2014			2013
	Proved-developed producing properties	$	6,663		$	6,424
	Proved-developed non producing properties		9,534			9,534
	Proved-undeveloped properties		9,972			9,972
	Less: Accumulated depletion		(2,759	)		(2,330	)
	Total oil and natural gas properties, net of accumulated depletion	$	23,410		$	23,600
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	Fair value of assets acquired and liabilities assumed
	Proved-developed producing properties	$	876
	Asset retirement obligation		(17	)
	Total fair value of assets acquired and liabilities assumed, net	$	859
	Consideration transferred
	Cash consideration paid directly by the Company	$	140
	Cash consideration paid through debt financing		322
	Stock to be issued at fair value		397
	Total consideration paid	$	859

Note_6_Other_Property_and_Equi1

Note 6 - Other Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment [Table Text Block]		2014			2013
	Field equipment	$	322		$	322
	Vehicles		512			512
	Office equipment		245			245
	Buildings		130			130
	Land		14			14
	Less: Accumulated depreciation		(825	)		(753	)
	Total other property and equipment, net of accumulated depreciation	$	398		$	470

Note_7_Asset_Retirement_Obliga1

Note 7 - Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Asset Retirement Obligations [Table Text Block]		2014		2013
	Asset retirement obligations, start of year	$	959	$	877
	Additions to asset retirement obligation		-		37
	Accretion of discount		31		45
	Asset retirement obligations, end of year	$	990	$	959

Note_8_Notes_Payable_Tables

Note 8 - Notes Payable (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Schedule of Maturities of Long-term Debt [Table Text Block]	2015	$	15,828,959
	2016		285,041
	2017		300,368
	2018		316,559
	2019		322,557
	Thereafter		252,054

Note_9_Deferred_Income_Taxes_T

Note 9 - Deferred Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]		2014			2013
	Income tax provision calculated using the federal statutory income tax rate	$	(576	)	$	(1,378	)
	Permanent differences and other		(657	)		2
	Oil and gas properties		10			-
	Asset retirement obligation		20			-
	Change in valuation allowance		(1,203	)		1,376
	Total income tax expense	$	-		$	-
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]		2014			2013
	Deferred tax assets
	Federal net operating loss carryforward	$	4,141		$	3,056
	Asset retirement obligations		337			326
	Total deferred tax assets		4,478			3,382
	Deferred tax liabilities
	Depletion and Depreciation		223			242
	Net deferred tax asset, before valuation allowance		4,255			3,140
	Valuation allowance		(4,255	)		(3,140	)
	Net deferred tax asset

Note_11_Derivative_Contracts_a1

Note 11 - Derivative Contracts, at Fair Value (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments [Table Text Block]		Long Exposure						Short Exposure
	Primary underlying risk	Notional			Number of			Notional			Number of
		Amounts(a)			Contracts(b)			Amounts(a)			Contracts(b)
	Commodity price
	Swap	$	-					$	1,064			6
	Options		384			6			1,002			6
		$	384			6		$	2,066			12
		Long Exposure						Short Exposure
	Primary underlying risk	Notional			Number of			Notional			Number of
		Amounts(c)			Contracts(d)			Amounts(c)			Contracts(d)
	Commodity price
	Swap	$	-			-		$	3,111			4
	Options		354			1			266			1
		$	354			1		$	3,377			5
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]		Derivative Assets			Derivative Liabilities			Amount of gain (loss)
	Primary underlying risk
	Commodity price
	Swaps	$	406		$	-		$	406
	Options		682			(409	)		273
	Gross total		1,088			(409	)		679
	Less: Master netting arrangements		1			(1	)
	Total	$	1,089		$	(410	)	$	679
		Derivative Assets			Derivative Liabilities			Amount of loss
	Primary underlying risk
	Commodity price
	Swaps	$	-		$	(135	)	$	(261	)
	Options		1			(9	)		(8	)
	Gross total		1			(144	)		(269	)
	Less: Master netting arrangements		1			(1	)		-
	Total	$	-		$	(143	)	$	(269	)
Derivative Instruments, Gain (Loss) [Table Text Block]		Realized gain (loss)			Unrealized gain (loss)			Total
	Primary underlying risk
	Commodity price
	Swaps	$	540		$	(115	)	$	425
	Options		281			(25	)		256
	Total	$	821		$	(140	)	$	681
		Realized loss			Unrealized loss			Total
	Primary underlying risk
	Commodity price
	Swaps	$	(104	)	$	(157	)	$	(261	)
	Options		-			(8	)		(8	)
	Total	$	(104	)	$	(165	)	$	(269	)

Note_1_Organization_and_Nature1

Note 1 - Organization and Nature of Operations (Details) (USD $)	0 Months Ended	1 Months Ended
In Thousands, except Share data, unless otherwise specified	9-May-13	Jul. 30, 2013	Dec. 31, 2014	Dec. 31, 2013
Series F Preferred Stock [Member] | Transcoastal [Member]
Note 1 - Organization and Nature of Operations (Details) [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired	99.20%
Series F Preferred Stock [Member]
Note 1 - Organization and Nature of Operations (Details) [Line Items]
Stock Issued During Period, Shares, Acquisitions	3,721,036
Preferred Stock, Capital Shares Reserved for Future Issuance	194,920		393,471	165,105
Preferred Stock Voting Rights Shares	1,170
Reverse Stock Split [Member]
Note 1 - Organization and Nature of Operations (Details) [Line Items]
Stockholders' Equity Note, Stock Split, Conversion Ratio		200
Transcoastal [Member]
Note 1 - Organization and Nature of Operations (Details) [Line Items]
Other Ownership Interests, Contributed Capital (in Dollars)				700

Note_2_Going_Concern_Considera1

Note 2 - Going Concern Consideration (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Going Concern [Abstract]
Working Capital (Deficit)	($15,429)
Retained Earnings (Accumulated Deficit)	-44,417	-42,572
Net Income (Loss) Attributable to Parent	-1,695	-4,053
Net Cash Provided by (Used in) Operating Activities	($1,481)	($1,654)

Note_3_Summary_of_Significant_1

Note 3 - Summary of Significant Accounting Policies (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Note 3 - Summary of Significant Accounting Policies (Details) [Line Items]
Cash Equivalents, at Carrying Value	$127,000	$63,000
FDIC Deposit Insurance Coverage	250,000
Cash, Uninsured Amount	0	44
Provision for Doubtful Accounts	0	0
Gain (Loss) on Disposition of Oil and Gas and Timber Property	0	0
Oil And Gas Property Full Cost Method Industry Standard Discount	10.00%
Other Asset Impairment Charges	0	0
Number of Reportable Segments	1	1
Impairment of Oil and Gas Properties	0	0
Goodwill, Impairment Loss	0	0
Deferred Finance Costs, Noncurrent, Gross	0	265,000
Loss on Turnkey Contracts		1,468,000
Production Tax Expense	210,000	199,000
Unrecognized Tax Benefits	0	0
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	0	0
Weighted Average Number Diluted Shares Outstanding Adjustment (in Shares)	4,898,940	1,374,500
Allocated Share-based Compensation Expense	669,000	270,000
Vehicles and Office Equipment [Member] | Minimum [Member]
Note 3 - Summary of Significant Accounting Policies (Details) [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Vehicles and Office Equipment [Member] | Maximum [Member]
Note 3 - Summary of Significant Accounting Policies (Details) [Line Items]
Property, Plant and Equipment, Useful Life	6 years
Field Equipment [Member]
Note 3 - Summary of Significant Accounting Policies (Details) [Line Items]
Property, Plant and Equipment, Useful Life	10 years
Building [Member]
Note 3 - Summary of Significant Accounting Policies (Details) [Line Items]
Property, Plant and Equipment, Useful Life	20 years
Incurred During Development of Wells [Member]
Note 3 - Summary of Significant Accounting Policies (Details) [Line Items]
Interest Costs Incurred	0	31,000
Arbitration Award [Member]
Note 3 - Summary of Significant Accounting Policies (Details) [Line Items]
Loss on Turnkey Contracts		580,000
Uncollectible Turn-key Contract Expenses [Member]
Note 3 - Summary of Significant Accounting Policies (Details) [Line Items]
Loss on Turnkey Contracts		$888,000

Note_4_Fair_Value_Measurements2

Note 4 - Fair Value Measurements (Details) - Assets and Liabilities Measured at Fair Value (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Assets (at fair value):
Money market mutual fund	$679	$63
Liabilities (at fair value):
Commodity derivative liabilities	410	143
Asset retirement obligations	990	959
Total liabilities (at fair value)	990	1,102
Fair Value, Inputs, Level 1 [Member]
Assets (at fair value):
Money market mutual fund	679	63
Fair Value, Inputs, Level 2 [Member]
Liabilities (at fair value):
Commodity derivative liabilities		143
Total liabilities (at fair value)		143
Fair Value, Inputs, Level 3 [Member]
Liabilities (at fair value):
Asset retirement obligations	990	959
Total liabilities (at fair value)	$990	$959

Note_5_Oil_and_Natural_Gas_Pro2

Note 5 - Oil and Natural Gas Properties (Details) (USD $)	12 Months Ended	4 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Aug. 31, 2013
Note 5 - Oil and Natural Gas Properties (Details) [Line Items]
Payments to Acquire Oil and Gas Property and Equipment (in Dollars)	$140
Joint Purchase Agreement [Member] | Minimum [Member]
Note 5 - Oil and Natural Gas Properties (Details) [Line Items]
Percentage of Working Interests, Acquisition of Oil and Gas Properties		0.25%
Percentage of Revenue Interests Acquisition of Oil and Gas Properties		0.19%
Joint Purchase Agreement [Member] | Maximum [Member]
Note 5 - Oil and Natural Gas Properties (Details) [Line Items]
Percentage of Working Interests, Acquisition of Oil and Gas Properties		100.00%
Percentage of Revenue Interests Acquisition of Oil and Gas Properties		81.25%
Joint Purchase Agreement [Member]
Note 5 - Oil and Natural Gas Properties (Details) [Line Items]
Payments to Acquire Oil and Gas Property and Equipment (in Dollars)		859

Note_5_Oil_and_Natural_Gas_Pro3

Note 5 - Oil and Natural Gas Properties (Details) - Summary of the Company's Oil and Natural Gas Properties (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Less: Accumulated depletion	($2,759)	($2,330)
Total oil and natural gas properties, net of accumulated depletion	23,410	23,600
Proved Developed Producing Properties [Member]
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Oil and Gas Property, Gross	6,663	6,424
Proved Developed Non Producing Properties [Member]
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Oil and Gas Property, Gross	9,534	9,534
Proved Undeveloped Properties [Member]
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]
Oil and Gas Property, Gross	$9,972	$9,972

Note_5_Oil_and_Natural_Gas_Pro4

Note 5 - Oil and Natural Gas Properties (Details) - Summary of the Assets and Liabilities Obtained (Joint Purchase Agreement [Member], USD $)	4 Months Ended
In Thousands, unless otherwise specified	Aug. 31, 2013
Fair value of assets acquired and liabilities assumed
Proved-developed producing properties	$876
Asset retirement obligation	-17
Total fair value of assets acquired and liabilities assumed, net	859
Consideration transferred
Stock to be issued at fair value	397
Total consideration paid	859
Cash Consideration Paid Directly by Company [Member]
Consideration transferred
Cash consideration paid	140
Cash Consideration Paid through Debt Financing [Member]
Consideration transferred
Cash consideration paid	$322

Note_6_Other_Property_and_Equi2

Note 6 - Other Property and Equipment (Details) - Other Property and Equipment (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]
Less: Accumulated depreciation	($825)	($753)
Total other property and equipment, net of accumulated depreciation	398	470
Field Equipment [Member]
Property, Plant and Equipment [Line Items]
Other Property and Equipment, Gross	322	322
Vehicles [Member]
Property, Plant and Equipment [Line Items]
Other Property and Equipment, Gross	512	512
Office Equipment [Member]
Property, Plant and Equipment [Line Items]
Other Property and Equipment, Gross	245	245
Building [Member]
Property, Plant and Equipment [Line Items]
Other Property and Equipment, Gross	130	130
Land [Member]
Property, Plant and Equipment [Line Items]
Other Property and Equipment, Gross	$14	$14

Note_7_Asset_Retirement_Obliga2

Note 7 - Asset Retirement Obligations (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]
Number of Oil and Gas Wells Evaluated	218	216

Note_7_Asset_Retirement_Obliga3

Note 7 - Asset Retirement Obligations (Details) - Reconciliation of Asset Retirement Obligations (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Reconciliation of Asset Retirement Obligations [Abstract]
Asset retirement obligations, start of year	$959	$877
Asset retirement obligations, end of year	990	959
Additions to asset retirement obligation		37
Accretion of discount	$31	$45

Note_8_Notes_Payable_Details

Note 8 - Notes Payable (Details) (USD $)	1 Months Ended	12 Months Ended	1 Months Ended	3 Months Ended	7 Months Ended	10 Months Ended
	Jun. 30, 2014	Dec. 31, 2014	Feb. 11, 2013	Jan. 15, 2013	Sep. 30, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Feb. 12, 2014	19-May-11	Oct. 21, 2013
Note 8 - Notes Payable (Details) [Line Items]
Debt, Current		15,750,000				$15,750,000	$17,500,000
Long-term Debt, Current Maturities		15,829,000				15,829,000	17,512,000
Dalton Lott [Member]
Note 8 - Notes Payable (Details) [Line Items]
Due to Related Parties	1,500,000
Related Party Transaction, Rate	5.50%
Debt Instrument, Term	60 months
Prime Rate [Member] | Green Bank [Member]
Note 8 - Notes Payable (Details) [Line Items]
Debt Instrument, Basis Spread on Variable Rate		-0.50%
Minimum [Member] | Green Bank [Member]
Note 8 - Notes Payable (Details) [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		4.50%				4.50%
Current Ratio		1				1
EBITDAX to Interest Expense Ratio		3.5				3.5		3.25	3
Maximum [Member] | Green Bank [Member]
Note 8 - Notes Payable (Details) [Line Items]
Total Liabilities to Tangible Net Worth Ratio		2				2
Green Bank [Member]
Note 8 - Notes Payable (Details) [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity										16,950,000	15,000,000
Debt Instrument, Interest Rate, Effective Percentage		4.50%				4.50%	4.50%
Debt Instrument, Periodic Payment, Principal			0	150,000	125,000	125,000
Notes Payable		15,750,000				15,750,000	17,500,000
Western Equipment Finance [Member]
Note 8 - Notes Payable (Details) [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity												74,000
Debt Instrument, Interest Rate, Stated Percentage												9.00%
Notes Payable		56,000				56,000	68
Long-term Debt, Current Maturities		12,000				$12,000

Note_8_Notes_Payable_Details_A

Note 8 - Notes Payable (Details) - Aggregate Future Maturities of Notes Payable (USD $)	Dec. 31, 2014
Aggregate Future Maturities of Notes Payable [Abstract]
2015	$15,828,959
2016	285,041
2017	300,368
2018	316,559
2019	322,557
Thereafter	$252,054

Note_9_Deferred_Income_Taxes_D

Note 9 - Deferred Income Taxes (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Income Tax Disclosure [Abstract]
Operating Loss Carryforwards	$12,179	$8,686

Note_9_Deferred_Income_Taxes_D1

Note 9 - Deferred Income Taxes (Details) - Reconcilation of Income Tax Expense (Benefit) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Reconcilation of Income Tax Expense (Benefit) [Abstract]
Income tax provision calculated using the federal statutory income tax rate	($576)	($1,378)
Permanent differences and other	-657	2
Oil and gas properties	10
Asset retirement obligation	20
Change in valuation allowance	-1,203	1,376
Total income tax expense	$0	$0

Note_9_Deferred_Income_Taxes_D2

Note 9 - Deferred Income Taxes (Details) - Components of Deferred Taxes (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Deferred tax assets
Federal net operating loss carryforward	$4,141	$3,056
Asset retirement obligations	337	326
Total deferred tax assets	4,478	3,382
Deferred tax liabilities
Depletion and Depreciation	223	242
Net deferred tax asset, before valuation allowance	4,255	3,140
Valuation allowance	-4,255	-3,140
Net deferred tax asset	$0	$0

Note_10_Shareholders_Equity_De

Note 10 - Shareholders' Equity (Details) (USD $)	12 Months Ended		1 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Jul. 30, 2013	Jul. 29, 2013	9-May-13
Note 10 - Shareholders' Equity (Details) [Line Items]
Common Stock, Shares, Outstanding	29,334,264	22,453,773	178,224	35,644,696
Stock Issued During Period, Value, Other (in Dollars)	$289
Other Assets, Noncurrent (in Dollars)	223	387
Stock Issued During Period, Shares, Share-based Compensation, Gross	825,829
Allocated Share-based Compensation Expense (in Dollars)	669	270
Common Stock, Shares Authorized	250,000,000	250,000,000
Common Stock, Par or Stated Value Per Share (in Dollars per share)	$0.00	$0.00
Preferred Stock, Shares Authorized	25,000,000	25,000,000
Preferred Stock, Par or Stated Value Per Share (in Dollars per share)	$0.00	$0.00
Common Stock, Shares, Issued	29,334,264	22,453,773
Common Stock, Capital Shares Reserved for Future Issuance	735,845	265,625
Stock Issued (in Dollars)	1,653
(in Dollars)	845	2,496
Series A Preferred Stock [Member] | Common Stock [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Convertible Preferred Stock, Shares Issued upon Conversion	2
Class of Warrant or Right, Number of Securities Called by Each Warrant or Right	1
Series A Preferred Stock [Member] | Warrant [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Convertible Preferred Stock, Shares Issued upon Conversion	1
Series A Preferred Stock [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Stock Issued During Period, Shares, New Issues	0	206,250
Preferred Stock, Dividend Rate, Percentage	8.00%
Proceeds from Issuance of Preferred Stock and Preference Stock (in Dollars)	0	679
Class of Warrant or Right, Outstanding, Exercisable Term	3 years
Class of Warrant or Right, Exercise Price of Warrants or Rights (in Dollars per share)	$3.50
Dividends, Preferred Stock (in Dollars)		266
Payments of Ordinary Dividends, Preferred Stock and Preference Stock (in Dollars)		39
Series G Preferred Stock [Member] | Common Stock [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Convertible Preferred Stock, Shares Issued upon Conversion	2
Class of Warrant or Right, Number of Securities Called by Each Warrant or Right	1
Series G Preferred Stock [Member] | Warrant [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Convertible Preferred Stock, Shares Issued upon Conversion	2
Series G Preferred Stock [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Stock Issued During Period, Shares, New Issues	603,000	687,250
Preferred Stock, Dividend Rate, Percentage	8.00%
Class of Warrant or Right, Outstanding, Exercisable Term	2 years
Class of Warrant or Right, Exercise Price of Warrants or Rights (in Dollars per share)	$3.75
Dividends, Preferred Stock (in Dollars)		1,756
Payments of Ordinary Dividends, Preferred Stock and Preference Stock (in Dollars)	103
Preferred Stock, Shares Issued	0	687,500
Preferred Stock, Shares Outstanding	0	687,500
Series H Preferred Stock [Member] | Common Stock [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Convertible Preferred Stock, Shares Issued upon Conversion	2
Class of Warrant or Right, Number of Securities Called by Each Warrant or Right	1
Series H Preferred Stock [Member] | Warrant [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Convertible Preferred Stock, Shares Issued upon Conversion	2
Series H Preferred Stock [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Stock Issued During Period, Shares, New Issues	1,125,000
Preferred Stock, Dividend Rate, Percentage	9.00%
Proceeds from Issuance of Preferred Stock and Preference Stock (in Dollars)	47
Class of Warrant or Right, Outstanding, Exercisable Term	2 years
Class of Warrant or Right, Exercise Price of Warrants or Rights (in Dollars per share)	$3.50
Preferred Stock, Shares Issued	1,125,000	0
Preferred Stock, Shares Outstanding	1,125,000	0
Series F Preferred Stock [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Preferred Stock, Capital Shares Reserved for Future Issuance	393,471	165,105			194,920
Common Stock [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Stock Issued During Period, Shares, New Issues	825,829
Stock Issued During Period, Shares, Other	1,335,000
Stock Issued During Period, Value, Other (in Dollars)	1
Stock Issued During Period, Shares, Issued for Services		207,467
Stock Issued During Period, Value, Issued for Services (in Dollars)		270
Investment Agreement with Third Party [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Maximum Aggregate Purchase Price of Common Shares (in Dollars)		5,000
Purchase Price of Common Stock, Percent of Lowest Daily Closing Bid Price of Common Stock		75.00%
Payments to Third Party to Facilitate Execution on Investment Agreement (in Dollars)		15
Stock Issued During Period, Shares, Other		256,578
Stock Issued During Period, Value, Other (in Dollars)		250
Other Assets, Noncurrent (in Dollars)		265
Reverse Stock Split [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Stockholders' Equity Note, Stock Split, Conversion Ratio			200
Maximum [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Common Stock, Shares, Outstanding			178,250
Directors and Officers [Member]
Note 10 - Shareholders' Equity (Details) [Line Items]
Stock Issued During Period, Shares, Share-based Compensation, Gross	2,139,162
Allocated Share-based Compensation Expense (in Dollars)	$669

Note_11_Derivative_Contracts_a2

Note 11 - Derivative Contracts, at Fair Value (Details) - Derivative Activities (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Swap [Member] | Long [Member]
Commodity price
Notional Amounts		[1]		[2]
Number of Contracts				[3]
Swap [Member] | Short [Member]
Commodity price
Notional Amounts	1,064	[1]	3,111	[2]
Number of Contracts	6	[3]	4	[3]
Commodity Option [Member] | Long [Member]
Commodity price
Notional Amounts	384	[1]	354	[2]
Number of Contracts	6	[3]	1	[3]
Commodity Option [Member] | Short [Member]
Commodity price
Notional Amounts	1,002	[1]	266	[2]
Number of Contracts	6	[3]	1	[3]
Long [Member]
Commodity price
Notional Amounts	384	[1]	354	[2]
Number of Contracts	6	[3]	1	[3]
Short [Member]
Commodity price
Notional Amounts	$2,066	[1]	$3,377	[2]
Number of Contracts	12	[3]	5	[3]
[1]	Notional amounts presented for contracts are based on the fair value of the underlying commodity as if the contracts were exercised at December 31, 2014.
[2]	Notional amounts presented for contracts are based on the fair value of the underlying commodity as if the contracts were exercised at December 31, 2013.
[3]	Number of contracts is presented in whole numbers.

Note_11_Derivative_Contracts_a3

Note 11 - Derivative Contracts, at Fair Value (Details) - Fair Value of Derivative Instruments (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Commodity price
Swaps, Derivative Assets	$1,088	$1
Swaps, Derivative Liabilities	-409	-144
Swaps, Amount of gain (loss)	679	-269
Less: Master netting arrangements, Derivative Assets	1	1
Less: Master netting arrangements, Derivative Liabilities	-1	-1
Total, Derivative Assets	1,089
Total, Derivative Liabilities	-410	-143
Total, Amount of gain (loss)	679	-269
Less: Master netting arrangements, Derivative Assets	1	1
Less: Master netting arrangements, Derivative Liabilities	-1	-1
Swap [Member]
Commodity price
Swaps, Derivative Assets	406
Swaps, Derivative Liabilities		-135
Swaps, Amount of gain (loss)	406	-261
Total, Amount of gain (loss)	406	-261
Commodity Option [Member]
Commodity price
Swaps, Derivative Assets	682	1
Swaps, Derivative Liabilities	-409	-9
Swaps, Amount of gain (loss)	273	-8
Total, Amount of gain (loss)	$273	($8)

Note_11_Derivative_Contracts_a4

Note 11 - Derivative Contracts, at Fair Value (Details) - Gain (Loss) on Derivative Instruments (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Primary underlying risk
Realized gain (loss)	$821	($104)
Unrealized gain (loss)	822	-165
Total	720	-269
Swap [Member]
Primary underlying risk
Realized gain (loss)	540	-104
Unrealized gain (loss)	-115	-157
Total	425	-261
Commodity Option [Member]
Primary underlying risk
Realized gain (loss)	281
Unrealized gain (loss)	-25	-8
Total	$256	($8)

Note_12_Related_Party_Transact1

Note 12 - Related Party Transactions (Details) (Dalton Lott [Member], USD $)	1 Months Ended
	Jun. 30, 2014
Dalton Lott [Member]
Note 12 - Related Party Transactions (Details) [Line Items]
Due to Related Parties	$1,500,000
Related Party Transaction, Rate	5.50%

Note_13_Commitments_and_Contin1

Note 13 - Commitments and Contingencies (Details) (USD $)	1 Months Ended	12 Months Ended		0 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2014	Dec. 31, 2013	Jan. 06, 2015
Note 13 - Commitments and Contingencies (Details) [Line Items]
Litigation Settlement, Amount	$580
Operating Leases, Rent Expense		182	193
Operating Leases, Future Minimum Payments Due		30
Subsequent Event [Member] | Subsequent Monthly Payments [Member]
Note 13 - Commitments and Contingencies (Details) [Line Items]
Litigation Settlement, Amount				5
Subsequent Event [Member]
Note 13 - Commitments and Contingencies (Details) [Line Items]
Litigation Settlement, Amount				$15

Note_14_Risk_Concentrations_De

Note 14 - Risk Concentrations (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Note 14 - Risk Concentrations (Details) [Line Items]
Number of Purchasers	9	11
Sales Revenue, Net [Member] | Minimum [Member] | Product Concentration Risk [Member]
Note 14 - Risk Concentrations (Details) [Line Items]
Concentration Risk, Percentage	11.80%	0.10%
Sales Revenue, Net [Member] | Maximum [Member] | Product Concentration Risk [Member]
Note 14 - Risk Concentrations (Details) [Line Items]
Concentration Risk, Percentage	31.10%	0.10%
TEXAS
Note 14 - Risk Concentrations (Details) [Line Items]
Number of Producing Leases	36	44

Note_15_Subsequent_Event_Detai

Note 15 - Subsequent Event (Details) (Subsequent Event [Member], USD $)	Feb. 20, 2015
Subsequent Event [Member]
Note 15 - Subsequent Event (Details) [Line Items]
Notes Payable	$15,750,000