Abraxas Petroleum (AXAS) 10-Q 8 May 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015	5-May-15
Document and Entity Information [Abstract]
Entity Registrant Name	ABRAXAS PETROLEUM CORP
Entity Central Index Key	867665
Current Fiscal Year End Date	-19
Entity Filer Category	Accelerated Filer
Document Type	10-Q
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Amendment Flag	FALSE
Entity Common Stock, Shares Outstanding		106,191,078

CONSOLIDATED_BALANCE_SHEET

CONSOLIDATED BALANCE SHEET (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Current assets:
Cash and cash equivalents	$3,869	$3,772
Accounts receivable:
Joint owners	3,419	5,648
Oil and gas production sales	8,625	15,308
Other	476	647
Total accounts receivable	12,520	21,603
Derivative asset	12,564	12,214
Other current assets	721	843
Total current assets	29,674	38,432
Oil and gas properties, full cost method of accounting:
Proved	729,684	716,922
Other property and equipment	40,871	40,683
Total	770,555	757,605
Less accumulated depreciation, depletion, and amortization	-447,345	-434,726
Total property and equipment, net	323,210	322,879
Deferred financing fees, net	2,078	2,216
Derivative asset	11,333	10,981
Other assets	255	391
Total assets	366,550	374,899
Current liabilities:
Accounts payable	21,038	63,549
Joint interest oil and gas production payable	8,520	14,423
Accrued interest	117	72
Other accrued expenses	1,129	1,006
Derivative liability	0	13
Current maturities of long-term debt	2,252	2,235
Total current liabilities	33,056	81,298
Long-term debt – less current maturities	116,152	76,554
Other liabilities	57	57
Future site restoration	9,689	9,495
Total liabilities	158,954	167,404
Commitments and contingencies
Stockholders’ Equity:
Preferred stock, par value $.01 per share – authorized 1,000,000 shares; -0- shares issued and outstanding	0	0
Common stock, par value $0.01 per share, authorized 200,000,000 shares; 106,191,078 and 106,186,678 issued and outstanding, respectively	1,062	1,062
Additional paid-in capital	310,592	309,773
Accumulated deficit	-104,058	-103,340
Total stockholders’ equity	207,596	207,495
Total liabilities and stockholders’ equity	$366,550	$374,899

CONSOLIDATED_BALANCE_SHEET_Par

CONSOLIDATED BALANCE SHEET (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
Stockholders’ Equity:
Preferred stock, par value (in dollars per share)	$0.01	$0.01
Preferred stock, shares authorized (in shares)	1,000,000	1,000,000
Preferred stock, shares issued (in shares)	0	0
Preferred stock, shares outstanding (in shares)	0	0
Common stock, par value (in dollars per share)	$0.01	$0.01
Common stock, shares authorized (in shares)	200,000,000	200,000,000
Common stock, shares issued (in shares)	106,191,078	106,186,678
Common stock, shares outstanding (in shares)	106,191,078	106,186,678

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Revenues:
Oil and gas production revenues	$18,646	$25,475
Other	15	43
Total revenue	18,661	25,518
Operating costs and expenses:
Lease operating	6,293	5,645
Production taxes	1,800	2,204
Depreciation, depletion, and amortization	12,069	7,499
General and administrative (including stock-based compensation of $810 and $439, respectively)	3,034	2,475
Operating expenses	23,196	17,823
Operating (loss) income	-4,535	7,695
Other (income) expense:
Interest income	-1	0
Interest expense	834	602
Amortization of deferred financing fees	157	348
(Gain) loss on derivative contracts - Realized	-3,633	734
(Gain) loss on derivative contracts - Unrealized	-1,194	945
Total other (income) expense	-3,837	2,629
(Loss) income from continuing operations before income tax	-698	5,066
Income tax (expense) benefit	0	0
Net (loss) income from continuing operations	-698	5,066
Net loss from discontinued operations	-20	-362
Net (loss) income	($718)	$4,704
Net (loss) income per common share - basic
Continuing operations (in dollars per share)	($0.01)	$0.05
Discontinued operations (in dollars per share)	$0	$0
Total (in dollars per share)	($0.01)	$0.05
Net (loss) income per common share - diluted
Continuing operations (in dollars per share)	($0.01)	$0.05
Discontinued operations (in dollars per share)	$0	$0
Total (in dollars per share)	($0.01)	$0.05
Denominator for basic earnings per share – weighted-average common shares outstanding (shares)	104,415	92,566
Weighted Average Number of Shares Outstanding, Diluted	104,415	94,321

CONSOLIDATED_STATEMENTS_OF_OPE1

CONSOLIDATED STATEMENTS OF OPERATIONS (Parenthetical) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Operating costs and expenses:
Stock-based compensation	$810	$439

CONSOLIDATED_STATEMENTS_OF_OTH

CONSOLIDATED STATEMENTS OF OTHER COMPREHENSIVE INCOME (LOSS) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Statement of Comprehensive Income [Abstract]
Consolidated net (loss) income	($718)	$4,704
Other comprehensive income (loss):
Foreign currency translation adjustment	0	-62
Other comprehensive (loss)	0	-62
Comprehensive (loss) income	($718)	$4,642

CONSOLIDATED_STATEMENTS_OF_STO

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (DEFICIT) (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Balance	$207,495
Balance (in shares)	106,186,678
Net income (loss)	-718	4,704
Balance	$207,596
Balance (in shares)	106,191,078

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Operating Activities
Net (loss) income	($718)	$4,704
Net loss from discontinued operations	-20	-362
Net (loss) from discontinued operations - net of tax	-698	5,066
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Change in derivative fair value	-715	613
Depreciation, depletion, and amortization	12,069	7,499
Amortization of deferred financing fees	157	348
Accretion of future site restoration	139	138
Stock-based compensation	810	439
Changes in operating assets and liabilities:
Accounts receivable	9,083	6,825
Other assets	258	105
Accounts payable and accrued expenses	-48,191	-18,355
Net cash (used in) provided by continuing operations	-27,088	2,678
Net cash used in discontinued operations	-20	-254
Net cash (used in) provided by continuing operations	-27,108	2,424
Investing Activities
Capital expenditures, including purchases and development of properties	-12,400	-36,686
Proceeds from the sale of oil and gas properties	0	2,619
Net cash used in continuing operations	-12,400	-34,067
Net cash provided by discontinued operations	0	130
Net cash used in investing activities	-12,400	-33,937
Financing Activities
Proceeds from long-term borrowings	40,000	27,000
Payments on long-term borrowings	-385	-370
Deferred financing fees	-19	1
Exercise of stock options	9	46
Other	0	-130
Net cash provided by continuing operations	39,605	26,547
Net cash provided by discontinued operations	0	109
Net cash provided by financing activities	39,605	26,656
Effect of exchange rate changes on cash - discontinued operations	0	1
Increase (decrease) in cash	97	-4,856
Cash at beginning of year	3,772	5,205
Cash at end of year	3,869	349
Supplemental disclosure of cash flow information:
Interest Paid	$649	$430

Basis_of_Presentation

Basis of Presentation	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Significant Accounting Policies	Basis of Presentation
	The accounting policies followed by Abraxas Petroleum Corporation and its subsidiaries (the “Company”) are set forth in the notes to the Company’s audited consolidated financial statements in the Annual Report on Form 10-K for the year ended December 31, 2014 filed with the SEC on March 13, 2015. Such policies have been continued without change. Also, refer to the notes to those financial statements for additional details of the Company’s financial condition, results of operations, and cash flows. All material items included in those notes have not changed except as a result of normal transactions in the interim, or as disclosed within this report. The accompanying interim condensed consolidated financial statements have not been audited by our independent registered public accountants, but in the opinion of management, reflect all adjustments necessary for a fair presentation of the financial position and results of operations. Any and all adjustments are of a normal and recurring nature. Although management believes the unaudited interim related disclosures in these condensed consolidated financial statements are adequate to make the information presented not misleading, certain information and footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been condensed or omitted pursuant to the rules and regulations of the SEC. The results of operations and the cash flows for the period ended March 31, 2015 are not necessarily indicative of the results to be expected for the full year. The condensed consolidated financial statements included herein should be read in conjunction with the consolidated audited financial statements and the notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2014.
	Consolidation Principles
	The terms “Abraxas,” “Abraxas Petroleum,” “we,” “us,” “our” or the “Company” refer to Abraxas Petroleum Corporation and all of its subsidiaries, including Raven Drilling, LLC (“Raven Drilling”).
	Rig Accounting
	In accordance with SEC Regulation S-X, no income is to be recognized in connection with contractual drilling services performed in connection with properties in which the Company or its affiliates holds an ownership, or other economic interest. Any income not recognized as a result of this limitation is to be credited to the full cost pool and recognized through lower amortization as reserves are produced.
	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
	New Accounting Standards and Disclosures
	Revenue Recognition
	The Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) in May 2014 which provides accounting guidance for all revenue arising from contracts to provide goods or services to customers. The requirements from the new ASU are effective for interim and annual periods beginning after December 15, 2016, and early adoption is not permitted. In April 2015, the FASB tentatively decided to defer the effective date by one year, making the guidance effective for interim and annual reporting periods beginning after December 15, 2017. The standard allows for either full retrospective adoption or modified retrospective adoption. At this time, we are evaluating the guidance to determine the method of adoption and the impact of this ASU on our financial statements and related disclosures, if any.
	Presentation of Debt Issuance Costs
	In April 2015, the FASB issued Simplifying the Presentation of Debt Issuance Costs, Subtopic 835-30 (ASU No. 2015-03), which amends existing guidance to require the presentation of debt issuance costs on the balance sheet as a deduction from the carrying amount of the related debt, instead of an asset. This guidance will be effective for interim and annual reporting periods beginning after December 15, 2015, and early adoption is permitted. Other than the prescribed reclassification of assets to an offset of debt on the consolidated balance sheets, Abraxas does not expect the implementation of ASU 2015-03 to have a material impact on its consolidated financial statements.
	Stock-based Compensation and  Option Plans
	Stock Options
	The Company currently utilizes a standard option-pricing model (i.e., Black-Scholes) to measure the fair value of stock options granted to employees and directors.
	The following table summarizes the Company’s stock-based compensation expense related to stock options for the periods presented:
	Three Months Ended
	March 31,
	2015				2014
	$	417			$	306
	The following table summarizes the Company’s stock option activity for the three months ended March 31, 2015 (shares in thousands):
						Weighted				Weighted
			Number			Average				Average
			of			Option				Grant
			Shares			Exercise				Date Fair
						Price Per				Value
						Share				Per Share
	Outstanding, December 31, 2014		5,885			$	2.88			$	2.06
	Granted		1,400			$	3.16			$	2.3
	Exercised		(4	)		$	2.22			$	1.6
	Outstanding, March 31, 2015		7,281			$	2.93			$	2.11
	Additional information related to stock options at March 31, 2015 and December 31, 2014 is as follows:
			March 31,			December 31,
			2015			2014
	Options exercisable		4,475			4,112
	As of March 31, 2015, there was approximately $5.1 million of unamortized compensation expense related to outstanding stock options that will be recognized in 2015 through 2018.
	Restricted Stock Awards
	Restricted stock awards are awards of common stock that are subject to restrictions on transfer and to a risk of forfeiture if the awardee terminates employment with the Company prior to the lapse of the restrictions. The fair value of such stock was determined using the closing price on the grant date and compensation expense is recorded over the applicable vesting periods.
	The following table summarizes the Company’s restricted stock activity for the three months ended March 31, 2015:
			Number			Weighted
			of			Average
			Shares			Grant Date
						Fair Value
						Per Share
	Unvested, December 31, 2014		1,776			$	3.43
	Granted		—			—
	Vested/Released		(5	)		3.33
	Forfeited		—			—
	Unvested, March 31, 2015		1,771			$	3.44
	The following table summarizes the Company’s stock-based compensation expense related to restricted stock for the periods presented:
	Three Months Ended
	March 31,
	2015				2014
	$	393			$	133
	As of March 31, 2015, there was approximately $4.3 million of unamortized compensation expense relating to outstanding restricted shares that will be recognized in 2015 through 2018.
	Oil and Gas Properties
	The Company follows the full cost method of accounting for oil and gas properties.  Under this method, all direct costs and certain indirect costs associated with the acquisition of properties and successful, as well as unsuccessful, exploration and development activities are capitalized. Depreciation, depletion, and amortization of capitalized oil and gas properties and estimated future development costs, excluding unproved properties, are based on the unit-of-production method based on proved reserves.  Net capitalized costs of oil and gas properties, less related deferred taxes, are limited by country, to the lower of the unamortized capitalized cost or the cost ceiling. The cost ceiling is calculated as PV-10, plus the cost of properties not being amortized, if any, plus the lower of cost or estimated fair value of unproved properties included in the costs being amortized, if any, less related income taxes. We calculate the projected income tax effect using the “short-cut” method for the cost ceiling test calculation. Costs in excess of the cost ceiling are charged to proved property impairment expense.  No gain or loss is recognized upon sale or disposition of oil and gas properties, except where the sale or disposition causes a significant change in the relationship between capitalized cost and the estimated quantity of proved reserves. We apply the full cost ceiling test on a quarterly basis on the date of the latest balance sheet presented. At March 31, 2015, our net capitalized costs of oil and gas properties did not exceed the cost ceiling of our estimated proved reserves.
	Restoration, Removal and Environmental Liabilities
	The Company is subject to extensive federal, state and local environmental laws and regulations. These laws regulate the discharge of materials into the environment and may require the Company to remove or mitigate the environmental effects of the disposal or release of petroleum substances at various sites.  Environmental expenditures are expensed or capitalized depending on their future economic benefit.  Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed.
	Liabilities for expenditures of a non-capital nature are recorded when environmental assessments and/or remediation is probable, and the costs can be reasonably estimated. Such liabilities are generally undiscounted unless the timing of cash payments for the liability or component are fixed or reliably determinable.
	The Company accounts for asset retirement obligations based on the guidance of ASC 410 which addresses accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs. ASC 410 requires that the fair value of a liability for an asset's retirement obligation be recorded in the period in which it is incurred and the corresponding cost capitalized by increasing the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the estimated useful life of the related asset. For all periods presented, we have included estimated future costs of abandonment and dismantlement in our full cost amortization base and amortize these costs as a component of our depletion expense in the accompanying condensed consolidated financial statements.
	The following table summarizes the Company’s asset retirement obligation transactions for the three months ended March 31, 2015 and the year ended December 31, 2014:
			March 31,				December 31,
2015			2014
Beginning asset retirement obligation		$	9,495			$	9,888
New wells placed on production and other		55				444
Deletions related to property disposals and plugging costs		—				(1,318		)
Accretion expense		139				559
Revisions and other		—				198
Discontinued operations		—				(276		)
Ending asset retirement obligation		$	9,689			$	9,495

Income_Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes
	The Company records income taxes using the liability method. Under this method, deferred tax assets and liabilities are determined based on differences between financial reporting and tax basis of assets and liabilities and are measured using the tax rates and laws expected to be in effect when the differences are expected to reverse.
	For the three months ended March 31, 2015, there was no current or deferred income tax expense or benefit due to loss carryforwards. Valuation allowances have been recorded against such benefits in prior periods.
	The Company accounts for uncertain tax positions under the provisions of ASC 740-10. The Company recognizes interest and penalties related to uncertain tax positions in income tax expense. As of March 31, 2015, the Company did not have any accrued interest or penalties related to uncertain tax positions. The tax years 2004 through 2014 remain open to examination by the tax jurisdictions to which the Company is subject.
	At December 31, 2014, the Company had, subject to the limitation discussed below, $145.5 million of net operating loss carryforwards for U.S. tax purposes.  The loss carryforward will expire in varying amounts through 2034, if not utilized.
	Uncertainties exist as to the future utilization of the operating loss carryforwards under the criteria set forth under ASC 740-10 “Income Taxes”. Therefore, we have established a valuation allowance of $60.1 million or deferred tax assets at December 31, 2014.

LongTerm_Debt

Long-Term Debt	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt
	The following is a description of the Company’s debt as of March 31, 2015 and December 31, 2014, respectively:
			31-Mar-15			31-Dec-14
			(In thousands)
	Senior secured credit facility		$	110,000		$	70,000
	Rig loan agreement		4,127			4,456
	Real estate lien note		4,277			4,333
			118,404			78,789
	Less current maturities		(2,252		)	(2,235		)
			$	116,152		$	76,554
	Credit Facility
	We have a senior secured credit facility with Société Générale, as administrative agent and issuing lender, and certain other lenders, which we refer to as the credit facility.  As of March 31, 2015, $110.0 million was outstanding under the credit facility.
	The credit facility has a maximum commitment of $300.0 million and availability is subject to a borrowing base. At March 31, 2015, we had a borrowing base of $165.0 million. The borrowing base is determined semi-annually by the lenders based upon our reserve reports, one of which must be prepared by our independent petroleum engineers and one of which may be prepared internally. The amount of the borrowing base is calculated by the lenders based upon their valuation of our proved reserves securing the facility utilizing these reserve reports and their own internal decisions. In addition, the lenders, in their sole discretion, are able to make one additional borrowing base redetermination during any six-month period between scheduled redeterminations and we are able to request one redetermination during any six-month period between scheduled redeterminations.  The borrowing base will be automatically reduced in connection with any sales of producing properties with a market value of 5% or more of our then-current borrowing base and in connection with any hedge termination which could reduce the collateral value by 5% or more. Our borrowing base can never exceed the $300.0 million maximum commitment amount.  Outstanding amounts under the credit facility bear interest at (a) the greater of (1) the reference rate announced from time to time by Société Générale, (2) the Federal Funds Rate plus 0.5%, and (3) a rate determined by Société Générale as the daily one-month LIBOR plus, in each case, (b)0.75%—1.75%, depending on the utilization of the borrowing base, or, if we elect LIBOR plus 1.75%—2.75%, depending on the utilization of the borrowing base. At March 31, 2015, the interest rate on the credit facility was 2.43% based on 1-month LIBOR borrowings and level of utilization.
	Subject to earlier termination rights and events of default, the stated maturity date of the credit facility is June 30, 2018. Interest is payable quarterly on reference rate advances and not less than quarterly on LIBOR advances. We are permitted to terminate the credit facility and are able, from time to time, to permanently reduce the lenders’ aggregate commitment under the credit facility in compliance with certain notice and dollar increment requirements.
	Each of our subsidiaries has guaranteed our obligations under the credit facility on a senior secured basis. Obligations under the credit facility are secured by a first priority perfected security interest, subject to certain permitted encumbrances, in all of our and our subsidiary guarantors’ material property and assets, other than Raven Drilling.
	Under the credit facility, we are subject to customary covenants, including certain financial covenants and reporting requirements.  We are required to maintain a current ratio, as of the last day of each quarter of not less than 1.00 to 1.00 and an interest coverage ratio of not less than 2.50 to 1.00.  We are also required as of the last day of each quarter to maintain a total debt to EBITDAX ratio of not more than 4.00 to 1.00.The current ratio is defined as the ratio of consolidated current assets to consolidated current liabilities.  For the purposes of this calculation, current assets include the portion of the borrowing base which is undrawn but excludes any cash deposited with a counter-party to a hedging arrangement and any assets representing a valuation account arising from the application of ASC 815 and ASC 410-20 and current liabilities exclude the current portion of long-term debt and any liabilities representing a valuation account arising from the application of ASC 815 and ASC 410-20.  The interest coverage ratio is defined as the ratio of consolidated EBITDAX to consolidated interest expense for the four fiscal quarters ended on the calculation date. For the purposes of this calculation, EBITDAX is defined as the sum of consolidated net income plus interest expense, oil and gas exploration expenses, income, franchise or margin taxes, depreciation, amortization, depletion and other non-cash charges including non-cash charges resulting from the application of ASC 718, ASC 815 and ASC 410-20 plus all realized net cash proceeds arising from the settlement or monetization of any hedge contracts plus expenses incurred in connection with the negotiation, execution, delivery and performance of the Credit Facility plus expenses incurred in connection with any acquisition permitted under the Credit Facility plus expenses incurred in connection with any offering of senior unsecured notes, subordinated debt or equity plus up to $1.0 million of extraordinary expenses in any 12-month period plus extraordinary losses minus all non-cash items of income which were included in determining consolidated net income, including all non-cash items resulting from the application of ASC 815 and ASC 410-20. Interest expense includes total interest, letter of credit fees and other fees and expenses incurred in connection with any debt. The total debt to EBITDAX ratio is defined as the ratio of total debt to consolidated EBITDAX for the four fiscal quarters ended on the calculation date.  For the purposes of this calculation, total debt is the outstanding principal amount of debt, excluding debt associated with the office building, Raven Drilling’s  rig loan and obligations with respect to surety bonds and derivative contracts.
	At March 31, 2015 we were in compliance with all of our debt covenants. As of March 31, 2015, the interest coverage ratio was 37.19 to 1.00, the total debt to EBITDAX ratio was 1.32 to 1.00, and our current ratio was 2.34 to 1.00.
	The credit facility contains a number of covenants that, among other things, restrict our ability to:
	•	incur or guarantee additional indebtedness;
	•	transfer or sell assets;
	•	create liens on assets;
	•	engage in transactions with affiliates other than on an “arm’s length” basis;
	•	make any change in the principal nature of our business; and
	•	permit a change of control.
	The credit facility also contains customary events of default, including nonpayment of principal or interest, violations of covenants, cross default and cross acceleration to certain other indebtedness, bankruptcy and material judgments and liabilities.
	Rig Loan Agreement
	On September 19, 2011, Raven Drilling entered into a rig loan agreement, secured by our Oilwell 2000 HP diesel electric drilling rig (the “Collateral”). The original principal amount of the note was $7.0 million and bears interest at 4.26%.  The note is payable in monthly interest and principal payments in the amount of $179,695. Subject to earlier prepayment provisions and events of default, the stated maturity date of the note is February 14, 2017. As of March 31, 2015 and December 31, 2014, $4.1 million and $4.5 million, respectively, was outstanding under the rig loan agreement.
	The Company has guaranteed Raven Drilling’s obligations under the rig loan agreement and associated note.  Obligations under the rig loan agreement are secured by a first priority perfected security interest, subject to certain permitted encumbrances, in the Collateral.
	Real Estate Lien Note
	We have a real estate lien note secured by a first lien deed of trust on the property and improvements which serves as our corporate headquarters. The note bears interest at a fixed rate of 4.25% and is payable in monthly installments of $34,354. Beginning August 20, 2018, the interest rate will adjust to the current bank prime rate plus 1.00% with a maximum rate of 7.25%. The maturity date of the note is July 20, 2023. As of March 31, 2015 and December 31, 2014, $4.3 million and $4.3 million, respectively, was outstanding on the note.

Earnings_per_Share

Earnings per Share	3 Months Ended
	Mar. 31, 2015
Earnings Per Share [Abstract]
Earnings per Share	Earnings per Share
	The following table sets forth the computation of basic and diluted earnings per share:
		Three Months Ended March 31,
		2015			2014
		(In thousands, except per share data)
	Numerator:
	Net (loss) income from continuing operations	$	(698	)	$	5,066
	Net loss from discontinued operations	(20		)	(362		)
		(718		)	4,704
	Denominator:
	Denominator for basic earnings per share – weighted-average common shares outstanding	104,415			92,566
	Effect of dilutive securities:	—			1,755
	Stock options and restricted shares
	Denominator for diluted earnings per share – adjusted weighted-average shares and assumed exercise of options and restricted shares	104,415			94,321
	Net income (loss) per common share - basic
	Continuing operations	$	(0.01	)	$	0.05
	Discontinued operations	—			—
		$	(0.01	)	$	0.05
	Net income (loss) per common share - diluted
	Continuing operations	$	(0.01	)	$	0.05
	Discontinued operations	—			—
		$	(0.01	)	$	0.05
	Basic earnings per share, excluding any dilutive effects of stock options and unvested restricted stock, is computed by dividing net income (loss) available to common stockholders by the weighted average number of common shares outstanding for the period. Diluted income (loss) per share is computed similar to basic; however diluted income (loss) per share reflects the assumed conversion of all potentially dilutive securities. For the three months ended March 31, 2015, 2,821 potential shares related to stock options and unvested restricted shares were excluded from the calculation of diluted income (loss) per share since their inclusion would have been anti-dilutive due to a loss incurred in the period. None of the dilutive shares were excluded for the three months ended March 31, 2014.

Hedging_Program_and_Derivative

Hedging Program and Derivatives	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Hedging Program and Derivatives	Hedging Program and Derivatives
	The derivative instruments we utilize are based on index prices that may and often do differ from the actual oil and gas prices realized in our operations.  Our derivative contracts do not qualify for hedge accounting as prescribed by ASC 815; therefore, fluctuations in the market value of the derivative contracts are recognized in earnings during the current period. There are no netting agreements relating to these derivative contracts and there is no policy to offset.
	The following table sets forth the summary position of our derivative contracts as of March 31, 2015:
		Oil - WTI					Gas
	Contract Periods	Daily Volume (Bbl)		Swap Price (per Bbl)			Daily Volume (Mcf)		Swap Price (per Mcf)
	2015	1,041		$	85.04		1,450		$	4.04
	2016	948		$	84.1		—		$	—
	2017	493		$	84.18		—		$	—
	The following table illustrates the impact of derivative contracts on the Company’s balance sheet:
	Fair Value of Derivative Instruments as of March 31, 2015
		Asset Derivatives				Liability Derivatives
	Derivatives not designated as hedging instruments	Balance Sheet Location	Fair Value			Balance Sheet Location	Fair Value
	Commodity price derivatives	Derivatives – current	$	12,564		Derivatives – current	$	—
	Commodity price derivatives	Derivatives – long-term	11,333			Derivatives – long-term	—
			$	23,897			$	—
	Fair Value of Derivative Instruments as of December 31, 2014
		Asset Derivatives				Liability Derivatives
	Derivatives not designated as hedging instruments	Balance Sheet Location	Fair Value			Balance Sheet Location	Fair Value
	Commodity price derivatives	Derivatives – current	$	12,214		Derivatives – current	$	13
	Commodity price derivatives	Derivatives – long-term	10,981			Derivatives – long-term	—
			$	23,195			$	13
	Gains and losses from derivative activities are reflected as “(Gain) loss on derivative contracts” in the accompanying Condensed Consolidated Statements of Operations.

Financial_Instruments

Financial Instruments	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Financial Instruments	Financial Instruments
	The Company applies ASC 820-10  which defines fair value, establishes a framework for measuring fair value, establishes a fair value hierarchy based on the quality of inputs used to measure fair value and enhances disclosure requirements for fair value measurements.
	Fair Value Hierarchy—ASC 820-10 establishes a three-level valuation hierarchy for disclosure of fair value measurements. The valuation hierarchy categorizes assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. The three levels are defined as follows:
	•	Level 1 – inputs to the valuation methodology are quoted prices (unadjusted) for identical assets or liabilities in active markets.
	•	Level 2 - inputs to the valuation methodology include quoted prices for similar assets and liabilities in active markets, and inputs that are observable for the asset or liability, either directly or indirectly, for substantially the full term of the financial instrument.
	•	Level 3 - inputs to the valuation methodology are unobservable and significant to the fair value measurement.
	A financial instrument’s categorization within the valuation hierarchy is based upon the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the asset or liability. The Company is further required to assess the creditworthiness of the counter-party to the derivative contract. The results of the assessment of non-performance risk, based on the counter-party’s credit risk, could result in an adjustment of the carrying value of the derivative instrument. The following tables sets forth information about the Company’s assets and liabilities measured at fair value on a recurring basis as of March 31, 2015 and December 31, 2014, and indicate the fair value hierarchy of the valuation techniques utilized by the Company to determine such fair value (in thousands):
			Quoted Prices		Significant
			in Active		Other
			Markets for		Observable		Significant		Balance as of
			Identical		Inputs		Unobservable		March 31,
			Assets		(Level 2)		Inputs (Level 3)		2015
			(Level 1)
	Assets:
	NYMEX Fixed Price Derivative contracts		$	—	$	23,897	$	—	$	23,897
	Total Assets		$	—	$	23,897	$	—	$	23,897
	Liabilities:
	NYMEX Fixed Price Derivative contracts		$	—	$	—	$	—	$	—
	Total Liabilities		$	—	$	—	$	—	$	—
			Quoted Prices		Significant
			in Active		Other
			Markets for		Observable		Significant		Balance as of
			Identical		Inputs		Unobservable		December 31,
			Assets		(Level 2)		Inputs (Level 3)		2014
			(Level 1)
	Assets:
	NYMEX Fixed Price Derivative contracts		$	—	$	23,195	$	—	$	23,195
	Total Assets		$	—	$	23,195	$	—	$	23,195
	Liabilities:
	NYMEX Fixed Price Derivative contracts		$	—	$	13	$	—	$	13
	Total Liabilities		$	—	$	13	$	—	$	13
	The Company’s derivative contracts consist of NYMEX-based fixed price commodity swaps. The NYMEX-based fixed price derivative contracts are indexed to NYMEX futures contracts, which are actively traded, for the underlying commodity and are commonly used in the energy industry. A number of financial institutions and large energy companies act as counter-parties to these type of derivative contracts. As the fair value of these derivative contracts is based on a number of inputs, including contractual volumes and prices stated in each derivative contract, current and future NYMEX commodity prices, and quantitative models that are based upon readily observable market parameters that are actively quoted and can be validated through external sources, we have characterized these derivative contracts as Level 2. In order to verify the third party valuation, we enter the various inputs into a model and compare our results to the third party for reasonableness.
	Other Financial Instruments
	The carrying amounts of our cash, cash equivalents, restricted cash, accounts receivable, accounts payable, and accrued liabilities approximate fair value because of the short-term maturities and/or liquid nature of these assets and liabilities. The carrying value of our debt approximates fair value as the interest rates are market rates and this debt is considered Level 2.

Discontinued_Operations

Discontinued Operations	3 Months Ended
	Mar. 31, 2015
Discontinued Operations and Disposal Groups [Abstract]
Discontinued Operations	Discontinued Operations
	On October 31, 2014, the Company closed on the sale of its Canadian subsidiary, Canadian Abraxas Petroleum, ULC ("Canadian Abraxas"). The sale was based on management's decision to discontinue Canadian operations due to continuing losses.
	Canadian Abraxas revenue, reported in discontinued operations for the three months ended March 31, 2014 was $0.4 million. Canadian Abraxas net loss, reported in discontinued operations for the three months ended March 31, 2014 was $0.4 million.

Contingencies_Litigation

Contingencies - Litigation	3 Months Ended
	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Contingencies - Litigation
	From time to time, the Company is involved in litigation relating to claims arising out of its operations in the normal course of business. At March 31, 2015, the Company was not involved in any legal proceedings that are expected, individually or in the aggregate, to have a material adverse effect on its operations.

Subsequent_Events_Notes

Subsequent Events (Notes)	3 Months Ended
	Mar. 31, 2015
Subsequent Events [Abstract]
Subsequent Events	Subsequent Event
	On May 5, 2015, the Company monetized the value of its remaining 2015 oil derivative contracts for total proceeds of approximately $4.6 million. Subsequently, Abraxas entered into collars for the periods from June 2015 through December 2015, on 2,000 Bbls/d with a floor of $55.00 and a ceiling of $70.00. The Company also added 1,000 Bbls/d for 2016 in a three way collar with a ceiling of $71.00, a floor of $60.00 and a sub-floor of $45.00.

Basis_of_Presentation_Policies

Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations	Consolidation Principles
	The terms “Abraxas,” “Abraxas Petroleum,” “we,” “us,” “our” or the “Company” refer to Abraxas Petroleum Corporation and all of its subsidiaries, including Raven Drilling, LLC (“Raven Drilling”).
Rig Accounting	Rig Accounting
	In accordance with SEC Regulation S-X, no income is to be recognized in connection with contractual drilling services performed in connection with properties in which the Company or its affiliates holds an ownership, or other economic interest. Any income not recognized as a result of this limitation is to be credited to the full cost pool and recognized through lower amortization as reserves are produced.
Use of Estimates	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Estimates of Proved Oil and Gas Reserves	Oil and Gas Properties
	The Company follows the full cost method of accounting for oil and gas properties.  Under this method, all direct costs and certain indirect costs associated with the acquisition of properties and successful, as well as unsuccessful, exploration and development activities are capitalized. Depreciation, depletion, and amortization of capitalized oil and gas properties and estimated future development costs, excluding unproved properties, are based on the unit-of-production method based on proved reserves.  Net capitalized costs of oil and gas properties, less related deferred taxes, are limited by country, to the lower of the unamortized capitalized cost or the cost ceiling. The cost ceiling is calculated as PV-10, plus the cost of properties not being amortized, if any, plus the lower of cost or estimated fair value of unproved properties included in the costs being amortized, if any, less related income taxes. We calculate the projected income tax effect using the “short-cut” method for the cost ceiling test calculation. Costs in excess of the cost ceiling are charged to proved property impairment expense.  No gain or loss is recognized upon sale or disposition of oil and gas properties, except where the sale or disposition causes a significant change in the relationship between capitalized cost and the estimated quantity of proved reserves. We apply the full cost ceiling test on a quarterly basis on the date of the latest balance sheet presented. At March 31, 2015, our net capitalized costs of oil and gas properties did not exceed the cost ceiling of our estimated proved reserves.
Share-Based Payments	Stock Options
	The Company currently utilizes a standard option-pricing model (i.e., Black-Scholes) to measure the fair value of stock options granted to employees and directors.
	The following table summarizes the Company’s stock-based compensation expense related to stock options for the periods presented:
	Three Months Ended
	March 31,
	2015				2014
	$	417			$	306
	The following table summarizes the Company’s stock option activity for the three months ended March 31, 2015 (shares in thousands):
						Weighted				Weighted
			Number			Average				Average
			of			Option				Grant
			Shares			Exercise				Date Fair
						Price Per				Value
						Share				Per Share
	Outstanding, December 31, 2014		5,885			$	2.88			$	2.06
	Granted		1,400			$	3.16			$	2.3
	Exercised		(4	)		$	2.22			$	1.6
	Outstanding, March 31, 2015		7,281			$	2.93			$	2.11
	Additional information related to stock options at March 31, 2015 and December 31, 2014 is as follows:
			March 31,			December 31,
			2015			2014
	Options exercisable		4,475			4,112
	As of March 31, 2015, there was approximately $5.1 million of unamortized compensation expense related to outstanding stock options that will be recognized in 2015 through 2018.
	Restricted Stock Awards
	Restricted stock awards are awards of common stock that are subject to restrictions on transfer and to a risk of forfeiture if the awardee terminates employment with the Company prior to the lapse of the restrictions. The fair value of such stock was determined using the closing price on the grant date and compensation expense is recorded over the applicable vesting periods.
	The following table summarizes the Company’s restricted stock activity for the three months ended March 31, 2015:
			Number			Weighted
			of			Average
			Shares			Grant Date
						Fair Value
						Per Share
	Unvested, December 31, 2014		1,776			$	3.43
	Granted		—			—
	Vested/Released		(5	)		3.33
	Forfeited		—			—
	Unvested, March 31, 2015		1,771			$	3.44
	The following table summarizes the Company’s stock-based compensation expense related to restricted stock for the periods presented:
	Three Months Ended
	March 31,
	2015				2014
	$	393			$	133
	As of March 31, 2015, there was approximately $4.3 million of unamortized compensation expense relating to outstanding restricted shares that will be recognized in 2015 through 2018.
Restricted Stock Awards	Restricted Stock Awards
	Restricted stock awards are awards of common stock that are subject to restrictions on transfer and to a risk of forfeiture if the awardee terminates employment with the Company prior to the lapse of the restrictions. The fair value of such stock was determined using the closing price on the grant date and compensation expense is recorded over the applicable vesting periods.
Restoration, Removal and Environmental Liabilities	Restoration, Removal and Environmental Liabilities
	The Company is subject to extensive federal, state and local environmental laws and regulations. These laws regulate the discharge of materials into the environment and may require the Company to remove or mitigate the environmental effects of the disposal or release of petroleum substances at various sites.  Environmental expenditures are expensed or capitalized depending on their future economic benefit.  Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed.
	Liabilities for expenditures of a non-capital nature are recorded when environmental assessments and/or remediation is probable, and the costs can be reasonably estimated. Such liabilities are generally undiscounted unless the timing of cash payments for the liability or component are fixed or reliably determinable.
	The Company accounts for asset retirement obligations based on the guidance of ASC 410 which addresses accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs. ASC 410 requires that the fair value of a liability for an asset's retirement obligation be recorded in the period in which it is incurred and the corresponding cost capitalized by increasing the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the estimated useful life of the related asset. For all periods presented, we have included estimated future costs of abandonment and dismantlement in our full cost amortization base and amortize these costs as a component of our depletion expense in the accompanying condensed consolidated financial statements.
	The following table summarizes the Company’s asset retirement obligation transactions for the three months ended March 31, 2015 and the year ended December 31, 2014:
			March 31,				December 31,
			2015				2014
	Beginning asset retirement obligation		$	9,495			$	9,888
	New wells placed on production and other		55				444
	Deletions related to property disposals and plugging costs		—				(1,318		)
	Accretion expense		139				559
	Revisions and other		—				198
	Discontinued operations		—				(276		)
	Ending asset retirement obligation		$	9,689			$	9,495
Revenue Recognition and Major Purchasers	he Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) in May 2014 which provides accounting guidance for all revenue arising from contracts to provide goods or services to customers. The requirements from the new ASU are effective for interim and annual periods beginning after December 15, 2016, and early adoption is not permitted. In April 2015, the FASB tentatively decided to defer the effective date by one year, making the guidance effective for interim and annual reporting periods beginning after December 15, 2017. The standard allows for either full retrospective adoption or modified retrospective adoption. At this time, we are evaluating the guidance to determine the method of adoption and the impact of this ASU on our financial statements and related disclosures, if any.
Other Comprehensive Income (Loss)

Basis_of_Presentation_Tables

Basis of Presentation (Tables)	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Stock Options Activity and Related Compensation Expense	The following table summarizes the Company’s stock-based compensation expense related to stock options for the periods presented:
	Three Months Ended
	March 31,
	2015				2014
	$	417			$	306
	The following table summarizes the Company’s stock option activity for the three months ended March 31, 2015 (shares in thousands):
						Weighted				Weighted
			Number			Average				Average
			of			Option				Grant
			Shares			Exercise				Date Fair
						Price Per				Value
						Share				Per Share
	Outstanding, December 31, 2014		5,885			$	2.88			$	2.06
	Granted		1,400			$	3.16			$	2.3
	Exercised		(4	)		$	2.22			$	1.6
	Outstanding, March 31, 2015		7,281			$	2.93			$	2.11
	Additional information related to stock options at March 31, 2015 and December 31, 2014 is as follows:
			March 31,			December 31,
			2015			2014
	Options exercisable		4,475			4,112
Schedule of Unvested Restricted Stock Activity and Related Compensation Expense	The following table summarizes the Company’s restricted stock activity for the three months ended March 31, 2015:
			Number			Weighted
			of			Average
			Shares			Grant Date
						Fair Value
						Per Share
	Unvested, December 31, 2014		1,776			$	3.43
	Granted		—			—
	Vested/Released		(5	)		3.33
	Forfeited		—			—
	Unvested, March 31, 2015		1,771			$	3.44
	The following table summarizes the Company’s stock-based compensation expense related to restricted stock for the periods presented:
	Three Months Ended
	March 31,
	2015				2014
	$	393			$	133
Asset Retirement Obligations	The following table summarizes the Company’s asset retirement obligation transactions for the three months ended March 31, 2015 and the year ended December 31, 2014:
			March 31,				December 31,
			2015				2014
	Beginning asset retirement obligation		$	9,495			$	9,888
	New wells placed on production and other		55				444
	Deletions related to property disposals and plugging costs		—				(1,318		)
	Accretion expense		139				559
	Revisions and other		—				198
	Discontinued operations		—				(276		)
	Ending asset retirement obligation		$	9,689			$	9,495

LongTerm_Debt_Tables

Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Long-term Debt	The following is a description of the Company’s debt as of March 31, 2015 and December 31, 2014, respectively:
		31-Mar-15			31-Dec-14
		(In thousands)
	Senior secured credit facility	$	110,000		$	70,000
	Rig loan agreement	4,127			4,456
	Real estate lien note	4,277			4,333
		118,404			78,789
	Less current maturities	(2,252		)	(2,235		)
		$	116,152		$	76,554
	The following is a description of the Company’s debt as of March 31, 2015 and December 31, 2014, respectively:
		31-Mar-15			31-Dec-14
		(In thousands)
	Senior secured credit facility	$	110,000		$	70,000
	Rig loan agreement	4,127			4,456
	Real estate lien note	4,277			4,333
		118,404			78,789
	Less current maturities	(2,252		)	(2,235		)
		$	116,152		$	76,554

Earnings_per_Share_Tables

Earnings per Share (Tables)	3 Months Ended
	Mar. 31, 2015
Earnings Per Share [Abstract]
Computation of Basic and Diluted Net Income (Loss) Per Share	The following table sets forth the computation of basic and diluted earnings per share:
		Three Months Ended March 31,
		2015			2014
		(In thousands, except per share data)
	Numerator:
	Net (loss) income from continuing operations	$	(698	)	$	5,066
	Net loss from discontinued operations	(20		)	(362		)
		(718		)	4,704
	Denominator:
	Denominator for basic earnings per share – weighted-average common shares outstanding	104,415			92,566
	Effect of dilutive securities:	—			1,755
	Stock options and restricted shares
	Denominator for diluted earnings per share – adjusted weighted-average shares and assumed exercise of options and restricted shares	104,415			94,321
	Net income (loss) per common share - basic
	Continuing operations	$	(0.01	)	$	0.05
	Discontinued operations	—			—
		$	(0.01	)	$	0.05
	Net income (loss) per common share - diluted
	Continuing operations	$	(0.01	)	$	0.05
	Discontinued operations	—			—
		$	(0.01	)	$	0.05

Hedging_Program_and_Derivative1

Hedging Program and Derivatives (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Contract Position	The following table sets forth the summary position of our derivative contracts as of March 31, 2015:
		Oil - WTI					Gas
	Contract Periods	Daily Volume (Bbl)		Swap Price (per Bbl)			Daily Volume (Mcf)		Swap Price (per Mcf)
	2015	1,041		$	85.04		1,450		$	4.04
	2016	948		$	84.1		—		$	—
	2017	493		$	84.18		—		$	—
Impact of Derivative Contracts on Balance Sheet	The following table illustrates the impact of derivative contracts on the Company’s balance sheet:
	Fair Value of Derivative Instruments as of March 31, 2015
		Asset Derivatives				Liability Derivatives
	Derivatives not designated as hedging instruments	Balance Sheet Location	Fair Value			Balance Sheet Location	Fair Value
	Commodity price derivatives	Derivatives – current	$	12,564		Derivatives – current	$	—
	Commodity price derivatives	Derivatives – long-term	11,333			Derivatives – long-term	—
			$	23,897			$	—
	Fair Value of Derivative Instruments as of December 31, 2014
		Asset Derivatives				Liability Derivatives
	Derivatives not designated as hedging instruments	Balance Sheet Location	Fair Value			Balance Sheet Location	Fair Value
	Commodity price derivatives	Derivatives – current	$	12,214		Derivatives – current	$	13
	Commodity price derivatives	Derivatives – long-term	10,981			Derivatives – long-term	—
			$	23,195			$	13

Financial_Instruments_Tables

Financial Instruments (Tables)	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Assets and Liabilities Measured at Fair Value	A financial instrument’s categorization within the valuation hierarchy is based upon the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the asset or liability. The Company is further required to assess the creditworthiness of the counter-party to the derivative contract. The results of the assessment of non-performance risk, based on the counter-party’s credit risk, could result in an adjustment of the carrying value of the derivative instrument. The following tables sets forth information about the Company’s assets and liabilities measured at fair value on a recurring basis as of March 31, 2015 and December 31, 2014, and indicate the fair value hierarchy of the valuation techniques utilized by the Company to determine such fair value (in thousands):
		Quoted Prices		Significant
		in Active		Other
		Markets for		Observable		Significant		Balance as of
		Identical		Inputs		Unobservable		March 31,
		Assets		(Level 2)		Inputs (Level 3)		2015
		(Level 1)
	Assets:
	NYMEX Fixed Price Derivative contracts	$	—	$	23,897	$	—	$	23,897
	Total Assets	$	—	$	23,897	$	—	$	23,897
	Liabilities:
	NYMEX Fixed Price Derivative contracts	$	—	$	—	$	—	$	—
	Total Liabilities	$	—	$	—	$	—	$	—
		Quoted Prices		Significant
		in Active		Other
		Markets for		Observable		Significant		Balance as of
		Identical		Inputs		Unobservable		December 31,
		Assets		(Level 2)		Inputs (Level 3)		2014
		(Level 1)
	Assets:
	NYMEX Fixed Price Derivative contracts	$	—	$	23,195	$	—	$	23,195
	Total Assets	$	—	$	23,195	$	—	$	23,195
	Liabilities:
	NYMEX Fixed Price Derivative contracts	$	—	$	13	$	—	$	13
	Total Liabilities	$	—	$	13	$	—	$	13

Basis_of_Presentation_Details

Basis of Presentation (Details) (USD $)	3 Months Ended		12 Months Ended
Share data in Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Number of Shares
Outstanding, December 31, 2014	5,885
Granted	1,400
Exercised	-4
Outstanding, March 31, 2015	7,281		5,885
Weighted Average Option Exercise Price Per Share
Outstanding, December 31, 2014	$2.88
Granted	$2.93		$2.88
Exercised	$3.16
Outstanding, March 31, 2015	$2.22
Weighted Average Grant Date Fair Value Per Share
Outstanding, December 31, 2014	$2.06
Granted	$2.30
Exercised	$1.60
Outstanding, March 31, 2015	$2.11		$2.06
Share-Based Payments [Abstract]
Options exercisable	4,475		4,112
Stock-based compensation expense	$810,000	$439,000
Entity's asset retirement obligation transactions [Roll Forward]
Beginning asset retirement obligation	9,495,000	9,888,000	9,888,000
New wells placed on production and other	55,000		444,000
Deletions related to property disposals and plugging costs	0		-1,318,000
Accretion expense	139,000	138,000	559,000
Revisions and other	0		198,000
Discontinued operations	0		-276,000
Ending asset retirement obligation	9,689,000		9,495,000
Employee Stock Option [Member]
Share-Based Payments [Abstract]
Stock-based compensation expense	417,000	306,000
Unamortized compensation cost expected to be recognized in 2015 through 2018	5,100,000
Restricted Stock [Member]
Number of Shares
Unvested, December 31, 2014	1,776
Granted	0
Vested/Released	-5
Forfeited	0
Unvested, March 31, 2015	1,771
Weighted Average Grant Date Fair Value Per Share (in US$ per share)
Unvested, December 31, 2014	$3.43
Granted	$0
Vested/Released	$3.33
Forfeited	$0
Unvested, March 31, 2015	$3.44
Share-Based Payments [Abstract]
Stock-based compensation expense	393,000	133,000
Unamortized compensation cost expected to be recognized in 2015 through 2018	$4,300,000

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Operating Loss Carryforwards [Line Items]
Income tax (expense) benefit	$0	$0
Deferred Tax Assets, Operating Loss Carryforwards, Domestic			145,500,000
Deferred Tax Assets, Valuation Allowance			$60,100,000

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	3 Months Ended	0 Months Ended
	Mar. 31, 2015	Feb. 14, 2012	Jul. 20, 2013	Dec. 31, 2014	Sep. 19, 2011
	borrowing_base				hp
	report
Long-term debt [Abstract]
Long-term debt	$118,404,000			$78,789,000
Less current maturities	-2,252,000			-2,235,000
Long-term debt – less current maturities	116,152,000			76,554,000
Credit Facility [Abstract]
Maximum borrowing capacity	300,000,000
Current borrowing base	165,000,000
Number of reserve reports prepared by independent petroleum engineers	1
Number of reserve report prepared internally	1
Number of borrowing base redetermination	1
Term of borrowing base redetermination	6 months
Description of variable rate basis	LIBOR
Financial covenants, minimum current ratio	1
Financial covenants, interest coverage ratio	2.5
Financial covenants, total debt To EBITDAX ratio	4
Interest Coverage Ratio	37.19
Total debt to ebitdax ratio	1.32
Current Ratio	2.34
Senior Secured Credit Facility [Member]
Long-term debt [Abstract]
Long-term debt	110,000,000			70,000,000
Credit Facility [Abstract]
Market value of property (in hundredths)	5.00%
Reduced collateral value (in hundredths)	5.00%
Percentage added to variable rate (in hundredths)	0.50%
Interest rate on credit facility (in hundredths)	2.43%
Maturity date of debt instrument	30-Jun-18
Senior Secured Credit Facility [Member] | Minimum [Member]
Credit Facility [Abstract]
Percentage added to reference rate (in hundredths)	0.75%
Percentage added to variable rate (in hundredths)	1.75%
Senior Secured Credit Facility [Member] | Maximum [Member]
Credit Facility [Abstract]
Percentage added to reference rate (in hundredths)	1.75%
Percentage added to variable rate (in hundredths)	2.75%
Rig Loan Agreement [Member]
Long-term debt [Abstract]
Long-term debt	4,127,000			4,456,000
Credit Facility [Abstract]
Maturity date of debt instrument		14-Feb-17
Rig Loan Agreement [Abstract]
Power of diesel electric drilling rig (in horsepower)					2,000
Amount that can be borrowed under rig loan agreement		7,000,000
Interest rate on debt (in hundredths)		4.26%
Real Estate Lien Note [Abstract]
Monthly installments of principal and interest	179,695
Real Estate Lien Note [Member]
Long-term debt [Abstract]
Long-term debt	4,277,000			4,333,000
Credit Facility [Abstract]
Maturity date of debt instrument	20-Jul-23
Real Estate Lien Note [Abstract]
Fixed interest rate on note (in hundredths)			4.25%
Monthly installments of principal and interest			$34,354
Interest rate adjustment over prime (in hundredths)	1.00%
Interest rate adjustment maximum over prime (in hundredths)	7.25%

Earnings_per_Share_Details

Earnings per Share (Details) (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Numerator [Abstract]
Net (loss) income from continuing operations	($698)	$5,066
Net loss from discontinued operations	-20	-362
Net (loss) income	($718)	$4,704
Denominator [Abstract]
Denominator for basic earnings per share – weighted-average common shares outstanding (shares)	104,415,000	92,566,000
Effect of dilutive securities [Abstract]
Stock options, restricted shares and warrants (in shares)	0	1,755,000
Dilutive potential common shares [Abstract]
Denominator for diluted earnings per share - adjusted weighted-average shares and assumed exercise of options, restricted shares and warrants (in shares)	104,415,000	94,321,000
Earnings Per Share, Basic [Abstract]
Continuing operations (in dollars per share)	($0.01)	$0.05
Discontinued operations (in dollars per share)	$0	$0
Total (in dollars per share)	($0.01)	$0.05
Earnings Per Share, Diluted [Abstract]
Continuing operations (in dollars per share)	($0.01)	$0.05
Discontinued operations (in dollars per share)	$0	$0
Total (in dollars per share)	($0.01)	$0.05
Stock options excluded from the calculation of diluted income (loss) per share (in shares)	2,821	0

Hedging_Program_and_Derivative2

Hedging Program and Derivatives (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
	bbl
Impact of derivative contracts on balance sheet [Abstract]
Derivative asset - current	$12,564	$12,214
Derivative asset - long-term	11,333	10,981
Derivative Assets	23,897	23,195
Derivative liability - current	0	13
Derivative Liabilities	0	13
Commodity Price Derivatives [Member] | Derivative Asset - Current [Member]
Impact of derivative contracts on balance sheet [Abstract]
Derivative asset - current		12,214
Commodity Price Derivatives [Member] | Derivative Asset - Long-Term [Member]
Impact of derivative contracts on balance sheet [Abstract]
Derivative asset - long-term		10,981
Commodity Price Derivatives [Member] | Derivative Liability - Current [Member]
Impact of derivative contracts on balance sheet [Abstract]
Derivative liability - current	0	13
Commodity Price Derivatives [Member] | Derivative Liability - Long-Term [Member]
Impact of derivative contracts on balance sheet [Abstract]
Derivative liability - long-term	$0	$0
Oil - WTI [Member] | 2015 [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Daily Volume (in Bbl)	1,041
Swap Price (in dollars per Bbl)	85.04
Oil - WTI [Member] | 2016 [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Daily Volume (in Bbl)	948
Swap Price (in dollars per Bbl)	84.1
Oil - WTI [Member] | 2017 [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Daily Volume (in Bbl)	493
Swap Price (in dollars per Bbl)	84.18
Oil - LLS [Member] | 2015 [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Daily Volume (in Bbl)	1,450
Swap Price (in dollars per Bbl)	4.04
Oil - LLS [Member] | 2016 [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Daily Volume (in Bbl)	0
Swap Price (in dollars per Bbl)	0
Oil - LLS [Member] | 2017 [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Daily Volume (in Bbl)	0
Swap Price (in dollars per Bbl)	0

Financial_Instruments_Details

Financial Instruments (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Assets [Abstract]
NYMEX Fixed Price Derivative contracts	$23,897	$23,195
Liabilities [Abstract]
NYMEX Fixed Price Derivative contracts	0	13
Recurring Basis [Member]
Assets [Abstract]
NYMEX Fixed Price Derivative contracts	23,897	23,195
Total Assets	23,897	23,195
Liabilities [Abstract]
NYMEX Fixed Price Derivative contracts	0	13
Total Liabilities	0	13
Recurring Basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]
Assets [Abstract]
NYMEX Fixed Price Derivative contracts	0	0
Total Assets	0	0
Liabilities [Abstract]
NYMEX Fixed Price Derivative contracts	0	0
Total Liabilities	0	0
Recurring Basis [Member] | Significant Other Observable Inputs (Level 2) [Member]
Assets [Abstract]
NYMEX Fixed Price Derivative contracts	23,897	23,195
Total Assets	23,897	23,195
Liabilities [Abstract]
NYMEX Fixed Price Derivative contracts	0	13
Total Liabilities	0	13
Recurring Basis [Member] | Significant Unobservable Inputs (Level 3) [Member]
Assets [Abstract]
NYMEX Fixed Price Derivative contracts	0	0
Total Assets	0	0
Liabilities [Abstract]
NYMEX Fixed Price Derivative contracts	0	0
Total Liabilities	$0	$0

Discontinued_Operations_Detail

Discontinued Operations (Details) (Canadian Abraxas Petroleum, UCL [Member], USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Canadian Abraxas Petroleum, UCL [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenue		$375,000
Net loss	$400,000

Subsequent_Events_Details

Subsequent Events (Details) (Subsequent Event [Member], USD $)	0 Months Ended
In Millions, unless otherwise specified	5-May-15	5-May-15
	bbl
Subsequent Event [Line Items]
Proceeds from monetization of remaining derivative contracts	$4.60
Daily Volume (in Bbl)	2,000
Derivative, Ceiling	70	70
Derivative, Floor	55	55
2016 [Member]
Subsequent Event [Line Items]
Daily Volume (in Bbl)	1,000
Derivative, Ceiling	71	71
Derivative, Floor	60	60
Derivative, Sub-Floor	45	45