Matador Resources (MTDR) 10-Q8 Nov 132013 Q3 Quarterly reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
Document and Entity Information	Sep. 30, 2013	Nov. 07, 2013
Document and Entity Information [Abstract]	'	'
Entity Registrant Name	'Matador Resources Co	'
Entity Central Index Key	'0001520006	'
Document Type	'10-Q	'
Document Period End Date	30-Sep-13	'
Amendment Flag	'false	'
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	65,633,487

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Statement of Financial Position [Abstract]	'	'
Deferred Tax Liabilities, Net, Noncurrent	$3,609	'
Current assets	'	'
Cash	6,330	2,095
Certificates of deposit	40	230
Accounts receivable	'	'
Oil and natural gas revenues	26,722	24,422
Joint interest billings	2,600	4,118
Other	1,077	974
Derivative instruments	1,037	4,378
Deferred Tax Assets, Net	1,948	'
Lease and well equipment inventory	687	877
Prepaid expenses	3,250	1,103
Total current assets	43,691	38,197
Oil and natural gas properties, full-cost method	'	'
Evaluated	951,736	763,527
Unproved and unevaluated	213,084	149,675
Other property and equipment	29,219	27,258
Less accumulated depletion, depreciation and amortization	-445,193	-349,370
Net property and equipment	748,846	591,090
Other assets	'	'
Derivative instruments	995	771
Deferred income taxes	'	411
Other assets	2,288	1,560
Total other assets	3,283	2,742
Total assets	795,820	632,029
Current liabilities	'	'
Accounts payable	20,280	28,120
Accrued liabilities	50,048	59,179
Royalties payable	10,352	6,541
Derivative instruments	4,178	670
Advances from joint interest owners	10	1,515
Income taxes payable	980	'
Deferred income taxes	'	411
Other current liabilities	87	56
Total current liabilities	85,935	96,492
Long-term liabilities	'	'
Borrowings under Credit Agreement	145,000	150,000
Asset retirement obligations	6,147	5,109
Other long-term liabilities	2,463	1,324
Total long-term liabilities	157,219	156,433
Commitments and contingencies (Note 9)	'	'
Shareholders' equity	'	'
Common stock - $0.01 par value, 80,000,000 shares authorized; 66,927,261 and 56,778,718 shares issued; and 65,625,418 and 55,577,667 shares outstanding, respectively	670	568
Additional paid-in capital	548,051	404,311
Retained deficit	14,710	-15,010
Treasury stock, at cost, 1,301,843 and 1,201,051 shares, respectively	-10,765	-10,765
Total shareholders' equity	552,666	379,104
Total liabilities and shareholders' equity	$795,820	$632,029

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (Unaudited) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Statement of Financial Position [Abstract]	'	'
Common stock, par value (usd per share)	$0.01	$0.01
Common stock, shares authorized	80,000,000	80,000,000
Common stock, shares issued	57,139,755	56,778,718
Common stock, shares outstanding	55,837,912	55,577,667
Treasury stock, shares	1,301,843	1,201,051

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Revenues	'	'	'	'
Oil and natural gas revenues	$81,868	$38,008	$199,367	$103,250
Realized gain on derivatives	-1,165	3,371	-519	11,147
Unrealized loss on derivatives	-9,327	-12,993	-6,626	-1,149
Total revenues	71,376	28,386	192,222	113,248
Expenses	'	'	'	'
Production taxes and marketing	6,559	2,822	15,107	7,605
Lease operating	8,569	6,491	29,608	17,511
Depletion, depreciation and amortization	26,127	21,680	74,593	52,799
Accretion of asset retirement obligations	86	59	248	170
Full-cost ceiling impairment	0	3,596	21,229	36,801
General and administrative	5,395	3,439	14,146	11,321
Total expenses	46,736	38,087	154,931	126,207
Operating (loss) income	24,640	-9,701	37,291	-12,959
Other income (expense)	'	'	'	'
Net loss on asset sales and inventory impairment	0	0	-192	-60
Interest expense	-2,038	-144	-4,919	-453
Interest and other income	66	55	181	157
Total other expense	-1,972	-89	-4,930	-356
Income (loss) before income taxes	22,668	-9,790	32,361	-13,315
Income tax provision (benefit)	'	'	'	'
Current	902	188	980	188
Deferred	1,661	-781	1,661	-1,430
Total income tax provision (benefit)	2,563	-593	2,641	-1,242
Net income (loss)	$20,105	($9,197)	$29,720	($12,073)
Basic	'	'	'	'
Basic (shares)	58,016	55,271	55,766	53,519
Diluted	'	'	'	'
Diluted (shares)	58,152	55,271	55,889	53,519
Class A	'	'	'	'
Basic	'	'	'	'
Basic (usd per share)	$0.35	($0.17)	$0.53	($0.23)
Diluted	'	'	'	'
Diluted (usd per share)	$0.35	($0.17)	$0.53	($0.23)
Basic	'	'	'	'
Basic (shares)	58,016	55,271	55,766	53,379
Diluted	'	'	'	'
Diluted (shares)	58,152	55,271	55,889	53,379
Class B	'	'	'	'
Basic	'	'	'	'
Basic (usd per share)	$0	$0	$0	($0.03)
Diluted	'	'	'	'
Diluted (usd per share)	$0	$0	$0	($0.03)
Basic	'	'	'	'
Basic (shares)	0	0	0	140
Diluted	'	'	'	'
Diluted (shares)	0	0	0	140

Condensed_Consolidated_Stateme1

Condensed Consolidated Statement of Changes in Shareholders' Equity (USD $)	Total	Common Stock	Additional Paid-In Capital	Retained Deficit	Treasury Stock
In Thousands, except Share data, unless otherwise specified	Total	Common Stock	Additional Paid-In Capital	Retained Deficit	Treasury Stock
Beginning Balance at Dec. 31, 2012	$379,104	$568	$404,311	($15,010)	($10,765)
Beginning Balance, shares at Dec. 31, 2012	55,577,667	56,779,000	'	'	1,201,000
Stock Issued During Period, Shares, New Issues	'	9,778,000	'	'	'
Stock Issued During Period, Value, New Issues	149,069	98	148,971	'	'
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs	-7,389	'	-7,389	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'
Common stock issued to Board advisors	38	0	38	0	0
Common stock issued to Board advisors, shares	'	16,000	'	'	'
Stock options expense related to equity based awards	882	0	882	0	0
Liability based stock option awards forfeited or expired	114	0	114	0	0
Restricted stock issued	'	4	-4	0	0
Restricted stock issued, shares	'	354,000	'	'	'
Restricted stock forfeited	-22	0	-22	0	0
Restricted stock forfeited, shares	'	'	'	'	101,000
Restricted stock and restricted stock units expense	1,150	0	1,150	0	0
Current period net loss	29,720	0	0	29,720	0
Ending Balance at Sep. 30, 2013	$552,666	$670	$548,051	$14,710	($10,765)
Ending Balance, shares at Sep. 30, 2013	55,837,912	66,927,000	'	'	1,302,000

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Cash Flows (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Operating activities	'	'
Net (loss) income	($29,720)	$12,073
Adjustments to reconcile net (loss) income to net cash provided by operating activities	'	'
Unrealized loss on derivatives	6,626	1,149
Depletion, depreciation and amortization	74,593	52,799
Accretion of asset retirement obligations	248	170
Full-cost ceiling impairment	21,229	36,801
Stock-based compensation expense	-2,763	223
Deferred income tax provision	1,661	-1,430
Net loss on asset sales and inventory impairment	192	60
Changes in operating assets and liabilities	'	'
Accounts receivable	-886	-8,718
Lease and well equipment inventory	198	-285
Prepaid expenses	-2,148	179
Other assets	-728	-650
Accounts payable, accrued liabilities and other current liabilities	-10,702	6,105
Royalties payable	-3,812	-4,065
Advances from joint interest owners	-1,505	1,782
Income taxes payable	980	188
Other long-term liabilities	1,139	406
Net cash provided by operating activities	127,192	80,325
Investing activities	'	'
Oil and natural gas properties capital expenditures	-257,216	-212,702
Expenditures for other property and equipment	-3,058	-5,297
Purchases of certificates of deposit	-61	-416
Maturities of certificates of deposit	251	1,485
Net cash used in investing activities	-260,084	-216,930
Financing activities	'	'
Repayments of borrowings under Credit Agreement	-130,000	-123,000
Borrowings under Credit Agreement	125,000	116,000
Proceeds from issuance of common stock	149,069	146,510
Swing Sale Profit	0	24
Cost to issue equity	-6,933	-11,599
Proceeds from stock options exercised	0	2,660
Taxes paid related to net share settlement of stock-based compensation	-9	0
Payment of dividends - Class B	0	-96
Net cash provided by financing activities	137,127	130,499
Increase (decrease) in cash	4,235	-6,106
Cash at beginning of period	2,095	10,284
Cash at end of period	$6,330	$4,178

Nature_of_Operations

Nature of Operations	9 Months Ended
Nature of Operations	Sep. 30, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
NATURE OF OPERATIONS	'
	NATURE OF OPERATIONS
	Matador Resources Company (“Matador” and, collectively with its subsidiaries, the “Company”) is an independent energy company engaged in the exploration, development, production and acquisition of oil and natural gas resources in the United States, with an emphasis on oil and natural gas shale and other unconventional plays. The Company’s current operations are focused primarily on the oil and liquids-rich portion of the Eagle Ford shale play in South Texas and the Wolfcamp and Bone Spring plays in the Permian Basin in Southeast New Mexico and West Texas. The Company also operates in the Haynesville shale and Cotton Valley plays in Northwest Louisiana and East Texas. In addition, the Company has a large exploratory leasehold position in Southwest Wyoming and adjacent areas of Utah and Idaho where it is testing the Meade Peak shale.
	On November 22, 2010, the company formerly known as Matador Resources Company, a Texas corporation founded on July 3, 2003, formed a wholly-owned subsidiary, Matador Holdco, Inc. Pursuant to the terms of a corporate reorganization that was completed on August 9, 2011, the former Matador Resources Company became a wholly-owned subsidiary of Matador Holdco, Inc. and changed its corporate name to MRC Energy Company, and Matador Holdco, Inc. changed its corporate name to Matador Resources Company.
	MRC Energy Company holds the primary assets of the Company and has four wholly-owned subsidiaries: Matador Production Company, MRC Permian Company, MRC Rockies Company and Longwood Gathering and Disposal Systems GP, Inc. Matador Production Company serves as the oil and natural gas operating entity. MRC Permian Company conducts oil and natural gas exploration and development activities in Southeast New Mexico and West Texas. MRC Rockies Company conducts oil and natural gas exploration and development activities in the Rocky Mountains and specifically in the states of Wyoming, Utah and Idaho. Longwood Gathering and Disposal Systems GP, Inc. serves as the general partner of Longwood Gathering and Disposal Systems, LP, which owns a majority of the pipeline systems and salt water disposal wells used in the Company’s operations, transports limited quantities of third-party natural gas and disposes of limited quantities of third-party salt water.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	'
	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	Interim Financial Statements, Basis of Presentation, Consolidation and Significant Estimates
	The unaudited condensed consolidated financial statements of Matador and its subsidiaries have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”) but do not include all of the information and footnotes required by generally accepted accounting principles in the United States of America (“U.S. GAAP”) for complete financial statements and should be read in conjunction with the Company’s audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012 filed with the SEC (the “Annual Report”). All intercompany accounts and transactions have been eliminated in consolidation. In management’s opinion, these interim unaudited condensed consolidated financial statements include all adjustments of a normal recurring nature necessary for a fair presentation of the Company’s consolidated financial position as of September 30, 2013, consolidated results of operations for the three and nine months ended September 30, 2013 and 2012, consolidated changes in shareholders’ equity for the nine months ended September 30, 2013 and consolidated cash flows for the nine months ended September 30, 2013 and 2012. Certain reclassifications have been made to prior period items to conform to the current period presentation. These reclassifications had no effect on previously reported results of operations, cash flows or retained earnings. Amounts as of December 31, 2012 are derived from the audited consolidated financial statements in the Annual Report.
	Accounting measurements at interim dates inherently involve greater reliance on estimates than at year end and the results for the interim periods shown in this report are not necessarily indicative of results to be expected for the full year due in part to volatility in oil, natural gas and natural gas liquids prices, global economic and financial market conditions, interest rates, access to sources of liquidity, estimates of reserves, drilling risks, geological risks, transportation restrictions, oil, natural gas and natural gas liquids supply and demand, market competition and interruptions of production.

	The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. These estimates and assumptions may also affect disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company’s consolidated financial statements are based on a number of significant estimates, including accruals for oil and natural gas revenues, accrued assets and liabilities primarily related to oil and natural gas operations, stock-based compensation, valuation of derivative instruments and oil and natural gas reserves. The estimates of oil and natural gas reserves quantities and future net cash flows are the basis for the calculations of depletion and impairment of oil and natural gas properties, as well as estimates of asset retirement obligations and certain tax accruals. While the Company believes its estimates are reasonable, changes in facts and assumptions or the discovery of new information may result in revised estimates. Actual results could differ from these estimates.

	Property and Equipment
	The Company uses the full-cost method of accounting for its investments in oil and natural gas properties. Under this method of accounting, all costs associated with the acquisition, exploration and development of oil and natural gas properties and reserves, including unproved and unevaluated property costs, are capitalized as incurred and accumulated in a single cost center representing the Company’s activities, which are undertaken exclusively in the United States. Such costs include lease acquisition costs, geological and geophysical expenditures, lease rentals on undeveloped properties, costs of drilling both productive and non-productive wells, capitalized interest on qualifying projects and general and administrative expenses directly related to exploration and development activities, but do not include any costs related to production, selling or general corporate administrative activities. The Company capitalized approximately $2.3 million and $1.7 million of its general and administrative costs for the nine months ended September 30, 2013 and 2012, respectively. The Company capitalized approximately $1.2 million and $1.0 million of its interest expense for the nine months ended September 30, 2013 and 2012, respectively.
	The net capitalized costs of oil and natural gas properties are limited to the lower of unamortized costs less related deferred income taxes or the cost center ceiling, with any excess above the cost center ceiling charged to operations as a full-cost ceiling impairment. The need for a full-cost ceiling impairment is assessed on a quarterly basis. The cost center ceiling is defined as the sum of (a) the present value discounted at 10 percent of future net revenues of proved oil and natural gas reserves, plus (b) unproved and unevaluated property costs not being amortized, plus (c) the lower of cost or estimated fair value of unproved and unevaluated properties included in the costs being amortized, if any, less (d) income tax effects related to the properties involved. Future net revenues from proved non-producing and proved undeveloped reserves are reduced by the estimated costs for developing these reserves. The fair value of the Company’s derivative instruments is not included in the ceiling test computation as the Company does not designate these instruments as hedge instruments for accounting purposes.
	The estimated present value of after-tax future net cash flows from proved oil and natural gas reserves is highly dependent on the commodity prices used in these estimates. These estimates are determined in accordance with guidelines established by the SEC for estimating and reporting oil and natural gas reserves. Under these guidelines, oil and natural gas reserves are estimated using then-current operating and economic conditions, with no provision for price and cost escalations in future periods except by contractual arrangements.
	The commodity prices used to estimate oil and natural gas reserves are based on unweighted, arithmetic averages of first-day-of-the-month oil and natural gas prices for the previous 12-month period. For the period from October 2012 through September 2013, these average oil and natural gas prices were $91.69 per Bbl and $3.605 per MMBtu (million British thermal units), respectively. For the period from October 2011 through September 2012, these average oil and natural gas prices were $91.48 per Bbl and $2.826 per MMBtu, respectively. In estimating the present value of after-tax future net cash flows from proved oil and natural gas reserves, the average oil prices were adjusted by property for quality, transportation and marketing fees and regional price differentials, and the average natural gas prices were adjusted by property for energy content, transportation and marketing fees and regional price differentials. At September 30, 2013 and 2012, the Company’s oil and natural gas reserves estimates were prepared by the Company’s engineering staff in accordance with guidelines established by the SEC and then audited for their reasonableness and conformance with SEC guidelines by Netherland, Sewell & Associates, Inc., independent reservoir engineers.

	Using the average commodity prices, as adjusted, to determine the Company’s estimated proved oil and natural gas reserves at September 30, 2013, the Company’s net capitalized costs less related deferred income taxes did not exceed the full-cost ceiling. As a result, the Company recorded no impairment to its net capitalized costs for the three months ended September 30, 2013. At March 31, 2013, the Company’s net capitalized costs less related deferred income taxes exceeded the full-cost ceiling by $13.7 million. The Company recorded an impairment charge of $21.2 million to its net capitalized costs and a deferred income tax credit of $7.5 million for the three months ended March 31, 2013. These charges are reflected in the Company’s unaudited condensed consolidated statement of operations for the nine months ended September 30, 2013. Using the average commodity prices, as adjusted, to determine the Company’s estimated proved oil and natural gas reserves at June 30, 2012 and September 30, 2012, the Company’s net capitalized costs less related deferred income taxes exceeded the full-cost ceiling by $21.3 million and $2.3 million, respectively. The Company recorded an impairment charge of $33.2 million and $3.6 million to its net capitalized costs and a deferred income tax credit of $11.9 million and $1.3 million, related to the full-cost ceiling limitation at June 30, 2012 and September 30, 2012, respectively. These charges are reflected in the Company's unaudited condensed consolidated statement of operations for the nine months ended September 30, 2012. Changes in oil and natural gas production rates, reserves estimates, future development costs and other factors will determine the Company’s actual ceiling test computation and impairment analyses in future periods.
	As a non-cash item, the full-cost ceiling impairment impacts the accumulated depletion and the net carrying value of the Company’s assets on its consolidated balance sheet, as well as the corresponding consolidated shareholders’ equity, but it has no impact on the Company’s consolidated net cash flows as reported.

	Capitalized costs of oil and natural gas properties are amortized using the unit-of-production method based upon production and estimates of proved reserves quantities. Unproved and unevaluated property costs are excluded from the amortization base used to determine depletion. Unproved and unevaluated properties are assessed for possible impairment on a periodic basis based upon changes in operating or economic conditions. This assessment includes consideration of the following factors, among others: the assignment of proved reserves, geological and geophysical evaluations, intent to drill, remaining lease term and drilling activity and results. Upon impairment, the costs of the unproved and unevaluated properties are immediately included in the amortization base. Dry holes are included in the amortization base immediately upon determination that the well is not productive.

	Earnings Per Common Share
	The Company reports basic earnings per common share, which excludes the effect of potentially dilutive securities, and diluted earnings per common share, which includes the effect of all potentially dilutive securities, unless their impact is anti-dilutive.
	Prior to the consummation of the Company’s initial public offering in February 2012, the Company had issued two classes of common stock, Class A and Class B. The holders of the Class B shares were entitled to be paid cumulative dividends at a per share rate of $0.26-2/3 annually out of funds legally available for the payment of dividends. These dividends were accrued and paid quarterly. Dividends declared during the nine months ended September 30, 2013 and 2012 totaled zero and $27,643, respectively. Class B dividends declared during the fourth quarter of 2011 and the first quarter of 2012 were paid during the first quarter of 2012 totaling $96,356. As of September 30, 2013, the Company had not paid any dividends to holders of the Class A shares. Concurrent with the completion of the Company’s initial public offering, all 1,030,700 shares of the Company’s Class B common stock were converted to Class A common stock on a one-for-one basis. The Class A common stock is now referred to as the common stock.
	The following are reconciliations of the numerators and denominators used to compute the Company’s basic and diluted distributed and undistributed earnings (loss) per common share as reported for the three and nine months ended September 30, 2013 and 2012 (in thousands, except per share data).


		Three Months Ended								Nine Months Ended
		September 30,								September 30,
		2013				2012				2013				2012
	Net income (loss) - numerator
	Net income (loss)	$	20,105			$	(9,197	)		$	29,720			$	(12,073	)

	Less dividends to Class B shareholders - distributed earnings	—				—				—				(28		)

	Undistributed earnings (loss)	$	20,105			$	(9,197	)		$	29,720			$	(12,101	)

	Weighted average common shares outstanding - denominator
	Basic
	Class A	58,016				55,271				55,766				53,379

	Class B	—				—				—				140

	Total	58,016				55,271				55,766				53,519

	Diluted
	Class A
	Weighted average common shares outstanding for basic earnings

	(loss) per share	58,016				55,271				55,766				53,379

	Dilutive effect of options and restricted stock units	136				—				123				—

	Class A weighted average common shares outstanding - diluted	58,152				55,271				55,889				53,379

	Class B
	Weighted average common shares outstanding - no associated

	dilutive shares	—				—				—				140

	Total diluted weighted average common shares outstanding	58,152				55,271				55,889				53,519



		Three Months Ended								Nine Months Ended
		September 30,								September 30,
2013				2012				2013				2012
Earnings (loss) per common share
Basic
Class A
Distributed earnings	$	—			$	—			$	—			$	—

Undistributed earnings (loss)	$	0.35			$	(0.17	)		$	0.53			$	(0.23	)

Total	$	0.35			$	(0.17	)		$	0.53			$	(0.23	)

Class B
Distributed earnings	$	—			$	—			$	—			$	0.2

Undistributed loss	$	—			$	—			$	—			$	(0.23	)

Total	$	—			$	—			$	—			$	(0.03	)

Diluted
Class A
Distributed earnings	$	—			$	—			$	—			$	—

Undistributed earnings (loss)	$	0.35			$	(0.17	)		$	0.53			$	(0.23	)

Total	$	0.35			$	(0.17	)		$	0.53			$	(0.23	)

Class B
Distributed earnings	$	—			$	—			$	—			$	0.2

Undistributed loss	$	—			$	—			$	—			$	(0.23	)

Total	$	—			$	—			$	—			$	(0.03	)

A total of 1,085,152 options to purchase shares of the Company’s Class A common stock and 151,051 restricted stock units were excluded from the calculations above for the three and nine months ended September 30, 2012, because their effects were anti-dilutive. Additionally, 233,349 restricted shares, which are participating securities, were excluded from the calculations above for the three and nine months ended September 30, 2012, as these security holders do not have the obligation to share in the losses of the Company.
Fair Value Measurements
The Company measures and reports certain assets and liabilities on a fair value basis. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). The Company follows Financial Accounting Standards Board (“FASB”) guidance establishing a fair value hierarchy that prioritizes the inputs to valuation methods used to measure fair value.
Recent Accounting Pronouncements
Balance Sheet. In January 2013, the FASB issued Accounting Standards Update, or ASU, 2013-01, Balance Sheet. The ASU clarifies the scope of ASU 2011-11 to limit the application of ASU 2011-11 to derivatives accounted for in accordance with Accounting Standards Codification, or ASC, 815, Derivatives and Hedging, including bifurcated embedded derivatives, repurchase and reverse repurchase agreements, and securities borrowing and securities lending transactions that are either offset in accordance with ASC 210-20-45 or ASC 815-10-45 or subject to an enforceable master netting arrangement or similar agreement. The Company adopted ASU 2013-01 effective January 1, 2013, together with the adoption of ASU 2011-11. The adoption of ASUs 2013-01 and 2011-11 did not have a material effect on the Company’s consolidated financial statements but did require certain additional disclosures (see Note 8).
Balance Sheet. In December 2011, the FASB issued ASU 2011-11, Balance Sheet. The requirements amend the disclosure requirements related to offsetting in ASC 210-20-50. The amendments require enhanced disclosures by requiring improved information about financial instruments and derivative instruments that are either (1) offset in accordance with either ASC 210-20-45 or ASC 815-10-45 or (2) subject to an enforceable master netting arrangement or similar agreement, irrespective of whether they are offset in accordance with either ASC 210-20-45 or ASC 815-10-45. The Company adopted ASU 2011-11 effective January 1, 2013, together with the adoption of ASU 2013-01. The adoption of ASUs 2011-11 and 2013-01 did not have a material effect on the Company’s consolidated financial statements but did require certain additional disclosures (see Note 8).

Asset_Retirement_Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
ASSET RETIREMENT OBLIGATIONS	'
	ASSET RETIREMENT OBLIGATIONS
	The following table summarizes the changes in the Company’s asset retirement obligations for the nine months ended September 30, 2013 (in thousands).



	Beginning asset retirement obligations	$	5,769

	Liabilities incurred during period	417

	Liabilities settled during period	(57		)
	Revisions in estimated cash flows	533

	Accretion expense	248

	Ending asset retirement obligations	6,910

	Less: current asset retirement obligations(1)	(763		)
	Long-term asset retirement obligations	$	6,147

	_______________

	(1)	Included in accrued liabilities in the Company’s unaudited condensed consolidated balance sheet at September 30, 2013.

Revolving_Credit_Agreement

Revolving Credit Agreement	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
REVOLVING CREDIT AGREEMENT	'
	REVOLVING CREDIT AGREEMENT
	On September 28, 2012, the Company amended and restated its revolving credit agreement. This third amended and restated credit agreement (the “Credit Agreement”) increased the maximum facility amount from $400.0 million to $500.0 million. The Credit Agreement matures December 29, 2016. MRC Energy Company is the borrower under the Credit Agreement. Borrowings are secured by mortgages on substantially all of the Company’s oil and natural gas properties and by the equity interests of all of MRC Energy Company’s wholly-owned subsidiaries, which are also guarantors. In addition, all obligations under the Credit Agreement are guaranteed by Matador Resources Company, the parent corporation. Various commodity hedging agreements with certain of the lenders under the Credit Agreement (or affiliates thereof) are also secured by the collateral of and guaranteed by the eligible subsidiaries of MRC Energy Company.
	The borrowing base under the Credit Agreement is determined semi-annually as of May 1 and November 1 by the lenders based primarily on the estimated value of the Company’s proved oil and natural gas reserves at December 31 and June 30 of each year, respectively. Both the Company and the lenders may request an unscheduled redetermination of the borrowing base once each between scheduled redetermination dates. During the first quarter of 2013, the lenders completed their review of the Company’s proved oil and natural gas reserves at December 31, 2012, and on March 11, 2013, the borrowing base was increased from $215.0 million to $255.0 million. In connection with this borrowing base redetermination, the conforming borrowing base was increased to $220.0 million. At that time, the Company also amended the Credit Agreement to include Capital One, N.A., BMO Harris Financing, Inc. (Bank of Montreal) and IberiaBank in the Company’s lending group, which also includes RBC, as administrative agent, Comerica Bank, Citibank, N.A., The Bank of Nova Scotia and SunTrust Bank. This March 11, 2013 redetermination constituted the regularly scheduled May 1 redetermination. In late April 2013, the Company requested an unscheduled redetermination of the borrowing base, and on June 4, 2013, the borrowing base was increased from $255.0 million to $280.0 million.

	On August 7, 2013, the borrowing base under the Credit Agreement was increased to $350.0 million and the conforming borrowing base was increased to $275.0 million. At that time, the Company amended the Credit Agreement to provide that the borrowing base will automatically be reduced to the conforming borrowing base at the earlier of (i) June 30, 2014 or (ii) concurrent with the issuance by the Company of senior unsecured notes in an amount greater than or equal to $10.0 million. This August redetermination constituted the regularly scheduled November 1 redetermination. The Company may request one additional unscheduled redetermination of its borrowing base prior to the next scheduled redetermination.
	In the event of a borrowing base increase, the Company is required to pay a fee to the lenders equal to a percentage of the amount of the increase, which is determined based on market conditions at the time of the borrowing base increase. If, upon a redetermination or the automatic reduction of the borrowing base to the conforming borrowing base, the borrowing base were to be less than the outstanding borrowings under the Credit Agreement at any time, the Company would be required to provide additional collateral satisfactory in nature and value to the lenders to increase the borrowing base to an amount sufficient to cover such excess or to repay the deficit in equal installments over a period of six months.

	In connection with the March, June and August 2013 borrowing base redeterminations, the Company incurred $1.1 million of additional deferred loan costs. These costs were included with the remaining unamortized balance of the deferred loan costs incurred previously. As a result, total deferred loan costs were $2.3 million at September 30, 2013, and these costs are being amortized over the term of the agreement, which approximates the amortization of these costs using the effective interest method. On September 12, 2013, using a portion of the net proceeds from its public equity offering, the Company repaid $130.0 million of its outstanding borrowings under the Credit Agreement. At September 30, 2013, the Company had $145.0 million in borrowings outstanding under the Credit Agreement and approximately $0.3 million in outstanding letters of credit issued pursuant to the Credit Agreement. At September 30, 2013, the outstanding borrowings bore interest at an effective interest rate of approximately 4.0% per annum. Subsequent to September 30, 2013, the Company borrowed an additional $15.0 million to fund a portion of its working capital requirements and the acquisition of additional leasehold interests. At November 7, 2013, the Company had $160.0 million in borrowings outstanding under the Credit Agreement and approximately $0.3 million in outstanding letters of credit issued pursuant to the Credit Agreement.
	If the Company borrows funds as a base rate loan, such borrowings will bear interest at a rate equal to the higher of (i) the prime rate for such day or (ii) the Federal Funds Effective Rate on such day, plus 0.50% or (iii) the daily adjusting LIBOR rate plus 1.0% plus, in each case, an amount from 0.75% to 3.00% of such outstanding loan depending on the level of borrowings under the agreement. If the Company borrows funds as a Eurodollar loan, such borrowings will bear interest at a rate equal to (i) the quotient obtained by dividing (A) the LIBOR rate by (B) a percentage equal to 100% minus the maximum rate during such interest calculation period at which RBC is required to maintain reserves on Eurocurrency Liabilities (as defined in Regulation D of the Board of Governors of the Federal Reserve System) plus (ii) an amount from 1.75% to 4.00% of such outstanding loan depending on the level of borrowings under the Credit Agreement. The interest period for Eurodollar borrowings may be one, two, three or six months as designated by the Company. A commitment fee of 0.375% to 0.50%, depending on the unused availability under the Credit Agreement, is also paid quarterly in arrears. The Company includes this commitment fee, any amortization of deferred financing costs (including origination, borrowing base increase and amendment fees) and annual agency fees as interest expense and in its interest rate calculations and related disclosures. Key financial covenants under the Credit Agreement require the Company to maintain (1) a current ratio, which is defined as consolidated total current assets plus the unused availability under the Credit Agreement divided by consolidated total current liabilities, of 1.0 or greater measured at the end of each fiscal quarter beginning June 30, 2014 and (2) a debt to EBITDA ratio, which is defined as total debt outstanding divided by a rolling four quarter EBITDA calculation, of 4.0 or less.
	Subject to certain exceptions, the Credit Agreement contains various covenants that limit the Company’s ability to take certain actions, including, but not limited to, the following:

	•	incur indebtedness or grant liens on any of its assets;

	•	enter into commodity hedging agreements;

	•	declare or pay dividends, distributions or redemptions;

	•	merge or consolidate;

	•	make any loans or investments;

	•	engage in transactions with affiliates; and

	•	engage in certain asset dispositions, including a sale of all or substantially all of its assets.


	If an event of default exists under the Credit Agreement, the lenders will be able to accelerate the maturity of the borrowings and exercise other rights and remedies. Events of default include, but are not limited to, the following events:

	•	failure to pay any principal or interest on the notes or any reimbursement obligation under any letter of credit when due or any fees or other amounts within certain grace periods;

	•	failure to perform or otherwise comply with the covenants and obligations in the Credit Agreement or other loan documents, subject, in certain instances, to certain grace periods;

	•	bankruptcy or insolvency events involving the Company; and

	•	a change of control, as defined in the Credit Agreement.
	At September 30, 2013, the Company believes that it was in compliance with the terms of its Credit Agreement.

Income_Taxes

Income Taxes	9 Months Ended
Income Taxes	Sep. 30, 2013
Income Tax Disclosure [Abstract]	'
INCOME TAXES	'
	INCOME TAXES
	The Company had an effective tax rate of 11.3% and 8.2% for the three and nine months ended September 30, 2013, respectively. Total income tax expense for the three and nine months ended September 30, 2013 differed from amounts computed by applying the U.S. federal statutory tax rates to pre-tax income due primarily to the reversal of a valuation allowance of approximately $6.7 million on the Company's federal deferred tax assets at September 30, 2013, as the Company's federal deferred tax liabilities exceeded its federal deferred tax assets at September 30, 2013, and the impact of permanent differences between book and taxable income. The Company had a net loss for the three and nine months ended September 30, 2012.

StockBased_Compensation

Stock-Based Compensation	9 Months Ended
Stock-Based Compensation	Sep. 30, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
STOCK-BASED COMPENSATION	'
	STOCK-BASED COMPENSATION
	In March 2013, the Company granted awards of options to purchase 507,500 and 284,292 shares of the Company’s common stock at exercise prices of $8.21 per share and $8.18 per share, respectively, to certain of its employees. The fair value of these awards was approximately $2.8 million. The Company also granted awards of 324,771 shares of restricted stock to certain of its employees in March 2013. The fair value of these restricted stock awards was approximately $2.4 million. All of these awards vest over a term of three or four years.
	In February 2013, options to purchase 408,000 shares of the Company’s common stock at $10.00 per share expired unexercised or were forfeited.

Derivative_Financial_Instrumen

Derivative Financial Instruments	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
DERIVATIVE FINANCIAL INSTRUMENTS	'
	DERIVATIVE FINANCIAL INSTRUMENTS
	From time to time, the Company uses derivative financial instruments to mitigate its exposure to commodity price risk associated with oil, natural gas and natural gas liquids prices. These instruments consist of put and call options in the form of costless collars and swap contracts. The Company records derivative financial instruments in its consolidated balance sheet as either assets or liabilities measured at fair value. The Company has elected not to apply hedge accounting for its existing derivative financial instruments. As a result, the Company recognizes the change in derivative fair value between reporting periods currently in its consolidated statement of operations as an unrealized gain or loss. The fair value of the Company’s derivative financial instruments is determined using purchase and sale information available for similarly traded securities. Comerica Bank, The Bank of Nova Scotia and RBC (or affiliates thereof) were the counterparties for the Company's commodity derivatives at September 30, 2013. The Company has considered the credit standings of the counterparties in determining the fair value of its derivative financial instruments.

	The Company has entered into various costless collar contracts to mitigate its exposure to fluctuations in oil prices, each with an established price floor and ceiling. For each calculation period, the specified price for determining the realized gain or loss pursuant to any of these transactions is the arithmetic average of the settlement prices for the NYMEX West Texas Intermediate oil futures contract for the first nearby month corresponding to the calculation period’s calendar month. When the settlement price is below the price floor established by one or more of these collars, the Company receives from the counterparty an amount equal to the difference between the settlement price and the price floor multiplied by the contract oil volume. When the settlement price is above the price ceiling established by one or more of these collars, the Company pays to the counterparty an amount equal to the difference between the settlement price and the price ceiling multiplied by the contract oil volume.
	The Company has also entered into various swap contracts to mitigate its exposure to fluctuations in oil prices, each with an established fixed price. For each calculation period, the specified price for determining the realized gain or loss pursuant to any of these transactions is the arithmetic average of the settlement prices for the NYMEX West Texas Intermediate oil futures contract for the first nearby month corresponding to the calculation period’s calendar month. When the settlement price is below the fixed price established by one or more of these swaps, the Company receives from the counterparty an amount equal to the difference between the settlement price and the fixed price multiplied by the contract oil volume. When the settlement price is above the fixed price established by one or more of these swaps, the Company pays to the counterparty an amount equal to the difference between the settlement price and the fixed price multiplied by the contract oil volume.
	The Company has entered into various costless collar transactions for natural gas, each with an established price floor and ceiling. For each calculation period, the specified price for determining the realized gain or loss to the Company pursuant to any of these transactions is the settlement price for the NYMEX Henry Hub natural gas futures contract for the delivery month corresponding to the calculation period’s calendar month for the last day of that contract period. When the settlement price is below the price floor established by one or more of these collars, the Company receives from the counterparty an amount equal to the difference between the settlement price and the price floor multiplied by the contract natural gas volume. When the settlement price is above the price ceiling established by one or more of these collars, the Company pays to the counterparty an amount equal to the difference between the settlement price and the price ceiling multiplied by the contract natural gas volume.
	The Company has entered into various swap contracts to mitigate its exposure to fluctuations in natural gas liquids (“NGL”) prices, each with an established fixed price. For each calculation period, the settlement price for determining the realized gain or loss to the Company pursuant to any of these transactions is the arithmetic average of any current month for delivery on the nearby month futures contracts of the underlying commodity, except for purity ethane, as stated on the “Mont Belvieu Spot Gas Liquids Prices: NON-TET prop” on the pricing date. The settlement price for purity ethane is the arithmetic average of any current month for delivery on the nearby month futures contracts as stated on the “Mont Belvieu Spot Gas Liquids Prices” on the pricing date. When the settlement price is below the fixed price established by one or more of these swaps, the Company receives from the counterparty an amount equal to the difference between the settlement price and the fixed price multiplied by the contract NGL volume. When the settlement price is above the fixed price established by one or more of these swaps, the Company pays to the counterparty an amount equal to the difference between the settlement price and the fixed price multiplied by the contract NGL volume.
	At September 30, 2013, the Company had various costless collar contracts open and in place to mitigate its exposure to oil and natural gas price volatility, each with a specific term (calculation period), notional quantity (volume hedged) and price floor and ceiling. Each contract is set to expire at varying times during 2013, 2014 and 2015.
	At September 30, 2013, the Company had various swap contracts open and in place to mitigate its exposure to oil and NGL price volatility, each with a specific term (calculation period), notional quantity (volume hedged) and fixed price. Each contract is set to expire at varying times during 2013 and 2014.

	The following is a summary of the Company’s open costless collar contracts for oil and natural gas and open swap contracts for oil and natural gas liquids at September 30, 2013.


	Commodity	Calculation Period		Notional			Price Floor			Price			Fair Value of
				Quantity			($/Bbl)			Ceiling			Asset
				(Bbl/month)						($/Bbl)			(Liability)
													(thousands)
	Oil	10/01/2013 - 12/31/2013		20,000			85			102.25			$	(131	)

	Oil	10/01/2013 - 12/31/2013		20,000			85			108.8			(22		)

	Oil	10/01/2013 - 12/31/2013		20,000			85			110.4			(13		)

	Oil	10/01/2013 - 12/31/2013		20,000			90			102.8			(105		)

	Oil	10/01/2013 - 12/31/2013		20,000			90			115			13

	Oil	10/01/2013 - 06/30/2014		8,000			90			114			101

	Oil	10/01/2013 - 06/30/2014		12,000			90			115.5			163

	Oil	10/01/2013 - 12/31/2014		12,200			85			100.4			(249		)

	Oil	01/01/2014 - 12/31/2014		15,000			85			97.5			(399		)

	Oil	01/01/2014 - 12/31/2014		30,000			85			98			(767		)

	Oil	01/01/2014 - 12/31/2014		12,000			85			100			(154		)

	Oil	01/01/2014 - 12/31/2014		15,000			87			97			(357		)

	Oil	01/01/2014 - 12/31/2014		20,000			88			95.6			(593		)

	Oil	01/01/2014 - 12/31/2014		20,000			90			97			(294		)

	Oil	01/01/2014 - 12/31/2014		12,000			90			97.9			(97		)

	Oil	01/01/2014 - 12/31/2014		15,000			90			97.9			(124		)

	Oil	01/01/2014 - 12/31/2014		15,000			90			98			(135		)

	Oil	01/01/2014 - 12/31/2014		15,000			90			101.15			133

	Total open oil costless collar contracts												(3,030		)


	Commodity	Calculation Period		Notional			Price Floor			Price			Fair Value of
				Quantity			($/MMBtu)			Ceiling			Asset
				(MMBtu/month)						($/MMBtu)			(Liability)
													(thousands)
	Natural Gas	10/01/2013 - 12/31/2013		100,000			3			3.83			(16	)

	Natural Gas	10/01/2013 - 12/31/2013		100,000			3			4.95			1

Natural Gas	10/01/2013 - 12/31/2013		100,000			3			4.96			1

Natural Gas	10/01/2013 - 12/31/2013		150,000			3			4.24			(5	)

Natural Gas	10/01/2013 - 12/31/2013		100,000			3.25			4.41			3

Natural Gas	10/01/2013 - 12/31/2013		100,000			3.25			4.44			3

Natural Gas	10/01/2013 - 12/31/2013		100,000			3.5			4.37			15

Natural Gas	10/01/2013 - 12/31/2013		80,000			3.75			4.57			54

Natural Gas	01/01/2014 - 12/31/2014		100,000			3			5.15			(2	)

Natural Gas	01/01/2014 - 12/31/2014		100,000			3.25			5.21			59

Natural Gas	01/01/2014 - 12/31/2014		100,000			3.25			5.22			60

Natural Gas	01/01/2014 - 12/31/2014		100,000			3.25			5.37			76

Natural Gas	01/01/2014 - 12/31/2014		100,000			3.25			5.42			79

Natural Gas	01/01/2014 - 12/31/2014		100,000			3.5			4.9			118

Natural Gas	01/01/2014 - 12/31/2014		100,000			3.75			4.77			227

Natural Gas	01/01/2015 - 12/31/2015		200,000			3.75			5.04			331

Total open natural gas costless collar contracts												1,004



Commodity	Calculation Period		Notional Quantity			Fixed Price			Fair Value of
			(Bbl/month)			($/Bbl)			Liability
									(thousands)
Oil	10/01/2013 - 12/31/2013		10,000			90.2			(341	)

Oil	10/01/2013 - 12/31/2013		10,000			90.65			(327	)

Total open oil swap contracts									(668	)


Commodity	Calculation Period		Notional Quantity			Fixed Price			Fair Value of Asset (Liability)
			(Gal/month)			($/Gal)			(thousands)
Purity Ethane	10/01/2013 - 12/31/2013		110,000			0.335			28

Purity Ethane	10/01/2013 - 12/31/2013		110,000			0.355			35

Propane	10/01/2013 - 12/31/2013		53,000			0.953			(20		)

Propane	10/01/2013 - 12/31/2013		106,000			0.96			(37		)

Propane	10/01/2013 - 12/31/2013		53,000			1.001			(12		)

Propane	10/01/2013 - 12/31/2013		150,000			1.103			16

Propane	01/01/2014 - 12/31/2014		116,000			0.95			(87		)

Propane	01/01/2014 - 12/31/2014		116,000			1.003			8

Propane	01/01/2014 - 12/31/2014		60,000			1.015			13

Normal Butane	10/01/2013 - 12/31/2013		14,700			1.455			3

Normal Butane	10/01/2013 - 12/31/2013		14,700			1.56			8

Normal Butane	10/01/2013 - 12/31/2013		21,000			1.575			12

Normal Butane	10/01/2013 - 12/31/2013		117,000			1.575			63

Normal Butane	01/01/2014 - 12/31/2014		17,500			1.54			57

Normal Butane	01/01/2014 - 12/31/2014		45,500			1.55			143

Isobutane	10/01/2013 - 12/31/2013		7,000			1.515			2

Isobutane	10/01/2013 - 12/31/2013		7,000			1.625			4

Isobutane	10/01/2013 - 12/31/2013		43,500			1.675			34

Isobutane	10/01/2013 - 12/31/2013		23,000			1.675			18

Isobutane	01/01/2014 - 12/31/2014		22,000			1.64			87

Isobutane	01/01/2014 - 12/31/2014		37,000			1.64			156

Natural Gasoline	10/01/2013 - 12/31/2013		12,000			2.025			(3		)

Natural Gasoline	10/01/2013 - 12/31/2013		12,000			2.085			—

Natural Gasoline	10/01/2013 - 12/31/2013		12,000			2.102			—

Natural Gasoline	10/01/2013 - 12/31/2013		36,000			2.105			1

Natural Gasoline	10/01/2013 - 12/31/2013		90,500			2.148			20

Natural Gasoline	01/01/2014 - 12/31/2014		30,000			1.97			(7		)

Natural Gasoline	01/01/2014 - 12/31/2014		41,000			2			6

Total open NGL swap contracts									548

Total open derivative financial instruments									$	(2,146	)
These derivative financial instruments are subject to master netting arrangements within specific commodity types, i.e., oil, natural gas and natural gas liquids, by counterparty. Derivative financial instruments with Counterparty A are not subject to master netting across commodity types, while derivative financial instruments with Counterparties B and C allow for cross-commodity master netting provided the settlement dates for the commodities are the same. The Company does not present different types of commodities with the same counterparty on a net basis in its consolidated balance sheet.

The following table presents the gross asset balances of the Company’s derivative financial instruments, the amounts subject to master netting arrangements, the amounts that the Company has presented on a net basis, the amounts subject to master netting across different commodity types that were presented on a gross basis and the location of these balances in its unaudited condensed consolidated balance sheet as of September 30, 2013 (in thousands).


Derivative Instruments	Gross				Gross amounts				Net amounts of				Amounts subject to master netting arrangements presented on a gross basis
	amounts of				netted in the				assets
	recognized				consolidated				presented in the
	assets				balance sheet				consolidated
									balance sheet
Counterparty A
Current assets	$	2,104			$	(2,104	)		$	—			$	—

Other assets	1,034				(909		)		125				—

Counterparty B

Current assets	1,741				(1,289		)		452				138

Other assets	1,553				(1,039		)		514				—

Counterparty C

Current assets	2,874				(2,289		)		585				301

Other assets	1,478				(1,122		)		356				—

Total	$	10,784			$	(8,752	)		$	2,032			$	439

The following table presents the gross liability balances of the Company’s derivative financial instruments, the amounts subject to master netting arrangements, the amounts that the Company has presented on a net basis, the amounts subject to master netting across different commodity types that were presented on a gross basis and the location of these balances in its unaudited condensed consolidated balance sheet as of September 30, 2013 (in thousands).


Derivative Instruments	Gross				Gross amounts				Net amounts of				Amounts subject to master netting arrangements presented on a gross basis
	amounts of				netted in the				liabilities
	recognized				consolidated				presented in the
	liabilities				balance sheet				consolidated
									balance sheet
Counterparty A
Current liabilities	$	3,329			$	(2,104	)		$	1,225			$	—

Long-term liabilities	909				(909		)		—				—

Counterparty B

Current liabilities	2,749				(1,289		)		1,460				138

Long-term liabilities	1,039				(1,039		)		—				—

Counterparty C

Current liabilities	3,782				(2,289		)		1,493				301

Long-term liabilities	1,122				(1,122		)		—				—

Total	$	12,930			$	(8,752	)		$	4,178			$	439


The following table presents the gross asset balances of the Company’s derivative financial instruments, the amounts subject to master netting arrangements, the amounts that the Company has presented on a net basis, the amounts subject to master netting across different commodity types that were presented on a gross basis and the location of these balances in its unaudited condensed consolidated balance sheet as of December 31, 2012 (in thousands).


Derivative Instruments	Gross				Gross amounts				Net amounts of				Amounts subject to master netting arrangements presented on a gross basis
	amounts of				netted in the				assets
	recognized				condensed				presented in the
	assets				consolidated				consolidated
					balance sheet				balance sheet
Counterparty A
Current assets	$	6,445			$	(2,373	)		$	4,072			$	—

Other assets	1,096				(370		)		726				—

Counterparty B

Current assets	530				(224		)		306				82

Other assets	384				(339		)		45				—

Total	$	8,455			$	(3,306	)		$	5,149			$	82

The following table presents the gross liability balances of the Company’s derivative financial instruments, the amounts subject to master netting arrangements, the amounts that the Company has presented on a net basis, the amounts subject to master netting across different commodity types that were presented on a gross basis and the location of these balances in its unaudited condensed consolidated balance sheet as of December 31, 2012 (in thousands).



Derivative Instruments	Gross				Gross amounts				Net amounts of				Amounts subject to master netting arrangements presented on a gross basis
	amounts of				netted in the				liabilities
	recognized				condensed				presented in the
	liabilities				consolidated				condensed
					balance sheet				consolidated
									balance sheet
Counterparty A
Current liabilities	$	2,373			$	(2,373	)		$	—			$	—

Long-term liabilities	370				(370		)		—				—

Counterparty B

Current liabilities	894				(224		)		670				82

Long-term liabilities	339				(339		)		—				—

Total	$	3,976			$	(3,306	)		$	670			$	82

The following table summarizes the location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations for the periods presented (in thousands).



			Three Months Ended								Nine Months Ended
			September 30,								September 30,
Type of Instrument	Location in Condensed Consolidated Statement of Operations		2013				2012				2013				2012
Derivative Instrument
Oil	Revenues: Realized (loss) gain on derivatives		$	(1,519	)		$	374			$	(1,984	)		$	1,093

Natural Gas	Revenues: Realized gain on derivatives		161				2,996				790				10,053

NGL’s	Revenues: Realized gain on derivatives		193				1				675				1

Realized (loss) gain on derivatives			(1,165		)		3,371				(519		)		11,147

Oil	Revenues: Unrealized loss on derivatives		(8,132		)		(9,053		)		(6,818		)		(7,364		)
Natural Gas	Revenues: Unrealized gain (loss) on derivatives		57				(3,985		)		(132		)		6,170

NGL’s	Revenues: Unrealized (loss) gain on derivatives		(1,252		)		45				324				45

Unrealized loss on derivatives			(9,327		)		(12,993		)		(6,626		)		(1,149		)
Total			$	(10,492	)		$	(9,622	)		$	(7,145	)		$	9,998

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
FAIR VALUE MEASUREMENTS	'
	FAIR VALUE MEASUREMENTS
	The Company measures and reports certain financial and non-financial assets and liabilities on a fair value basis. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). Fair value measurements are classified and disclosed in one of the following categories.


	Level 1	Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. Active markets are considered to be those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis.


	Level 2	Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability. This category includes those derivative instruments that are valued using observable market data. Substantially all of these inputs are observable in the marketplace throughout the full term of the derivative instrument, can be derived from observable data or supported by observable levels at which transactions are executed in the marketplace.


	Level 3	Unobservable inputs that are not corroborated by market data. This category is comprised of financial and non-financial assets and liabilities whose fair value is estimated based on internally developed models or methodologies using significant inputs that are generally less readily observable from objective sources.
	Financial and non-financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels.
	At September 30, 2013 and December 31, 2012, the carrying values reported on the unaudited condensed consolidated balance sheets for accounts receivable, prepaid expenses, accounts payable, accrued liabilities, royalties payable, advances from joint interest owners, income taxes payable and other current liabilities approximate their fair values due to their short-term maturities and are classified at Level 1.
	At September 30, 2013 and December 31, 2012, the carrying value of borrowings under the Credit Agreement approximates fair value as it is subject to short-term floating interest rates that reflect market rates available to the Company at the time and is classified at Level 2.
	The following tables summarize the valuation of the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis in accordance with the classifications provided above as of September 30, 2013 and December 31, 2012 (in thousands).


		Fair Value Measurements at
		September 30, 2013 using
	Description	Level 1			Level 2				Level 3				Total
	Assets (Liabilities)
	Certificates of deposit	$	—		$	40			$	—			$	40

	Oil, natural gas and NGL derivatives	—			2,032				—				2,032

	Oil, natural gas and NGL derivatives	—			(4,178		)		—				(4,178		)

	Total	$	—		$	(2,106	)		$	—			$	(2,106	)



		Fair Value Measurements at
		December 31, 2012 using
	Description	Level 1			Level 2				Level 3				Total
	Assets (Liabilities)
	Certificates of deposit	$	—		$	230			$	—			$	230

	Oil, natural gas and NGL derivatives	—			5,149				—				5,149

	Oil, natural gas and NGL derivatives	—			(670		)		—				(670		)

	Total	$	—		$	4,709			$	—			$	4,709

	Additional disclosures related to derivative financial instruments are provided in Note 8. For purposes of fair value measurement, the Company determined that certificates of deposit and derivative financial instruments (e.g., oil, natural gas and NGL derivatives) should be classified at Level 2.
	The Company accounts for additions to asset retirement obligations and lease and well equipment inventory when adjusted for impairment at fair value on a non-recurring basis. The following tables summarize the valuation of the Company’s assets and liabilities that were accounted for at fair value on a non-recurring basis for the periods ended September 30, 2013 and December 31, 2012 (in thousands).


		Fair Value Measurements at
		September 30, 2013 using
	Description	Level 1			Level 2				Level 3				Total
	Assets (Liabilities)
	Asset retirement obligations	$	—		$	—			$	(951	)		$	(951	)

	Total	$	—		$	—			$	(951	)		$	(951	)



		Fair Value Measurements at
		December 31, 2012 using
	Description	Level 1			Level 2				Level 3				Total
	Assets (Liabilities)
	Asset retirement obligations	$	—		$	—			$	(1,243	)		$	(1,243	)

Lease and well equipment inventory	—			—				34				34

Total	$	—		$	—			$	(1,209	)		$	(1,209	)

For purposes of fair value measurement, the Company determined that additions and revisions to asset retirement obligations should be classified at Level 3. The Company recorded additions to asset retirement obligations and revisions of estimated cash flows of approximately $1.0 million for the nine months ended September 30, 2013 and $1.2 million for the year ended December 31, 2012.

For purposes of fair value measurement, the Company determined that lease and well equipment inventory should be classified at Level 3 when adjusted for impairment. No impairment to any equipment was recorded during the three months ended September 30, 2013. In 2012, the Company recorded an impairment to some of its equipment held in inventory consisting primarily of drilling rig parts of $425,000 and pipe and other equipment of $60,464. The Company periodically obtains estimates of the market value of its equipment held in inventory from an independent third-party contractor or seller of similar equipment and uses these estimates as a basis for its measurement of the fair value of this equipment.

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
Commitments and Contingencies	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENTS AND CONTINGENCIES	'
	Office Lease
	The Company’s corporate headquarters are located at One Lincoln Centre, 5400 LBJ Freeway, Suite 1500, Dallas, Texas. In April 2013, the Company entered into the fifth amendment to its office lease agreement. This amendment increased the square footage of its corporate headquarters to 40,071 square feet effective July 1, 2013. The lease expires on June 30, 2022.
	Natural Gas and NGL Processing and Transportation Commitments
	Effective September 1, 2012, the Company entered into a firm five-year natural gas processing and transportation agreement whereby the Company committed to transport the anticipated natural gas production from a significant portion of its Eagle Ford acreage in South Texas through the counterparty’s system for processing at the counterparty’s facilities. The agreement also includes firm transportation of the natural gas liquids extracted at the counterparty’s processing plant downstream for fractionation. After processing, the residue natural gas is purchased by the counterparty at the tailgate of its processing plant and further transported under its firm natural gas transportation agreements. The arrangement contains fixed processing and liquids transportation and fractionation fees, and the revenue the Company receives varies with the quality of natural gas transported to the processing facilities and the contract period.
	Under this agreement, if the Company does not meet 80% of the maximum thermal quantity transportation and processing commitments in a contract year, it will be required to pay a deficiency fee per MMBtu of natural gas deficiency. Any quantity in excess of the maximum MMBtu delivered in a contract year can be carried over to the next contract year for purposes of calculating the natural gas deficiency. The Company believes that its current and anticipated production from the wells covered by this agreement is sufficient to meet 80% of the maximum thermal quantity transportation and processing commitments under this agreement. The Company’s remaining aggregate undiscounted minimum commitments under this agreement are $12.2 million at September 30, 2013. The Company paid approximately $2.0 million and $3.8 million in processing and transportation fees under this agreement during the three and nine months ended September 30, 2013.

	Other Commitments
	From time to time, the Company enters into contracts with third parties for drilling rigs. These contracts establish daily rates for the drilling rigs and the term of the Company’s commitment for the drilling services to be provided, which are typically for one year or less. Should the Company elect to terminate a contract and if the drilling contractor were unable to secure work for the contracted drilling rigs or if the drilling contractor were unable to secure work for the contracted drilling rigs at the same daily rates being charged to the Company prior to the end of their respective contract terms, the Company would incur termination obligations. The Company’s maximum outstanding aggregate termination obligations under its drilling rig contracts were approximately $7.7 million at September 30, 2013.
	At September 30, 2013, the Company had agreed to participate in the drilling and completion of various non-operated wells. If all of these wells are drilled and completed, the Company will have minimum outstanding aggregate commitments for its participation in these wells of approximately $16.7 million at September 30, 2013, which it expects to incur within the next few months.
	Legal Proceedings
	Cynthia Fry Peironnet, et al. v. MRC Energy Company f/k/a Matador Resources Company. The Company was involved in a dispute over a mineral rights lease involving certain acreage in Louisiana. The dispute regarded an extension of the term of a lease in Caddo Parish, Louisiana (the “Lease”) where the Company had drilled or participated in the drilling of both Cotton Valley and Haynesville shale wells. At issue were the deep rights below the Cotton Valley formation on approximately 1,805 gross acres where the Company has the right to participate for up to a 25% working interest, and also retains a small overriding royalty interest, in Haynesville shale wells drilled in units that include portions of the acreage. The Company’s total net revenue and overriding royalty interests in several non-operated Haynesville shale wells previously drilled on this acreage range from approximately 2% to 23%, and only portions of these interests are attributable to this acreage. The sum of the Company’s overriding royalty and net revenue interests attributable to this acreage from Haynesville wells previously drilled on this acreage comprises less than one net well.

	The plaintiffs brought this claim against the Company on May 15, 2008 in the First Judicial District Court, Caddo Parish, Louisiana (the “Trial Court”). The plaintiffs sought (i) reformation or rescission of the lease extension, (ii) an accounting for additional royalty, (iii) monetary damages and (iv) attorney’s fees. During the pendency of the case in the Trial Court, the Company settled with one lessor who owned a 1/6th undivided interest in the minerals. The Trial Court rendered multiple rulings in favor of the Company, including a unanimous jury verdict in favor of the Company in the fall of 2010. Final judgment of the Trial Court was rendered in favor of the Company on June 6, 2011. On August 1, 2012, the Louisiana Second Circuit Court of Appeal (the “Court of Appeal”) affirmed in part and reversed in part the judgment of the Trial Court and remanded the case to the Trial Court for determination of damages. The Court of Appeal affirmed the Trial Court with respect to the 1/6th royalty owner that settled and also affirmed that the Company’s lease extension was unambiguous. Nonetheless, the Court of Appeal reformed the lease extension to cover only approximately 169 gross acres, holding that the deep rights covering the remaining 1,636 gross acres had expired. The Court of Appeal denied the Company’s motion for rehearing, and the Company and certain other defendants filed an appeal with the Louisiana Supreme Court. The Louisiana Supreme Court granted the requests to hear an appeal of the Court of Appeal’s decision, and in June 2013, the Louisiana Supreme Court reversed the decision of the Court of Appeal and reinstated the Trial Court judgment in its entirety. The plaintiffs filed an application for rehearing with the Louisiana Supreme Court, which was denied on August 30, 2013.

	MRC Energy Company f/k/a Matador Resources Company v. Orca ICI Development, J.V. The Company and Orca, a non-operator working interest owner, had various disputes regarding certain of the Company’s Eagle Ford shale wells and properties. Among other things, issues arose with respect to the rights and obligations of the Company and Orca under various agreements between the parties, and Orca sought the Company’s consent to Orca’s proposed assignment of its 50 percent working interest in the Cowey #3H and #4H wells to a non-industry person, despite the presence of a uniform maintenance of interest provision. On April 2, 2013, Orca brought suit against the Company in the 57th Judicial District Court of Bexar County, Texas and sought injunctive relief. The court denied Orca’s demand for injunctive relief, and on April 5, 2013, the Company moved to enforce arbitration provisions in the agreements between the parties. On April 22, 2013, the Company initiated an arbitration against Orca, seeking, among other things, a declaration that the Company could withhold its consent to Orca’s putative assignment of these interests. Pursuant to agreements reached between the parties in May and June 2013, Orca and the Company agreed to resolve all outstanding issues between the parties regarding the respective rights and obligations of the parties under the agreements between them. In addition, the Company agreed to bear 100% of the costs to drill, complete and equip the Cowey #3H and #4H wells. Until such time as the Company has recovered 100% of the costs to drill, complete and equip the wells, all revenues generated by production from these two wells will be attributable to the Company. Following the Company’s recovery of these amounts, Orca would participate in the wells for a 25% working interest. The Company has returned $8.7 million submitted by Orca’s putative assignee. The agreements also included a mutual release of claims between the Company and Orca and provided for the dismissal of the Bexar County litigation. Orca filed a notice of non-suit on August 7, 2013.
	The Company is a defendant in several other lawsuits encountered in the ordinary course of its business. In the opinion of management, it is remote that these lawsuits will have a material adverse impact on the Company’s financial position, results of operations or cash flows.

Supplemental_Disclosures

Supplemental Disclosures	9 Months Ended
	Sep. 30, 2013
Supplemental Disclosures [Abstract]	'
SUPPLEMENTAL DISCLOSURES	'
	SUPPLEMENTAL DISCLOSURES
	Accrued Liabilities
	The following table summarizes the Company’s current accrued liabilities at September 30, 2013 and December 31, 2012 (in thousands).



		September 30,			December 31,
		2013			2012
	Accrued evaluated and unproved and unevaluated property costs	$	38,879		$	45,592

	Accrued support equipment and facilities costs	228			1,382

	Accrued cost to issue equity	456			—

	Accrued stock-based compensation	—			65

	Accrued lease operating expenses	5,656			5,218

	Accrued interest on borrowings under Credit Agreement	117			255

	Accrued asset retirement obligations	763			660

	Accrued partners’ share of joint interest charges	890			3,597

	Other	3,059			2,410

	Total accrued liabilities	$	50,048		$	59,179


	Supplemental Cash Flow Information
	The following table provides supplemental disclosures of cash flow information for the nine months ended September 30, 2013 and 2012 (in thousands).


		Nine Months Ended
		September 30,
		2013			2012
	Cash paid for interest expense, net of amounts capitalized	$	2,110		$	442

	Asset retirement obligations related to mineral properties	889			405

	Asset retirement obligations related to support equipment and facilities	4			54

	(Decrease) increase in liabilities for oil and natural gas properties capital expenditures	(6,288		)	19,067

	(Decrease) increase in liabilities for support equipment and facilities	(1,100		)	482

	Increase (decrease) in liabilities for accrued cost to issue equity	456			(332		)

	Issuance of restricted stock units for Board and advisor services	186			34

	Issuance of common stock for advisor services	25			71

	Stock-based compensation expense recognized as liability	715			(930		)

	Transfer of inventory from oil and natural gas properties	201			(91		)

Subsidiary_Guarantors

Subsidiary Guarantors	9 Months Ended
Subsidiary Guarantors	Sep. 30, 2013
Subsidiary Guarantors [Abstract]	'
SUBSIDIARY GUARANTORS	'
	SUBSIDIARY GUARANTORS
	Matador filed a registration statement on Form S-3 with the SEC, which became effective May 9, 2013, and registered, among other securities, debt securities. The subsidiaries of Matador (the “Subsidiaries”) are co-registrants with Matador, and the registration statement registers guarantees of debt securities by the Subsidiaries. As of September 30, 2013, the Subsidiaries are 100 percent owned by Matador and any guarantees by the Subsidiaries will be full and unconditional (except for customary release provisions). Matador has no assets or operations independent of the Subsidiaries, and there are no significant restrictions upon the ability of the Subsidiaries to distribute funds to Matador. In the event that more than one of the Subsidiaries provide guarantees of any debt securities issued by Matador, such guarantees will constitute joint and several obligations.

Subsequent_Events

Subsequent Events	9 Months Ended
Subsequent Events	Sep. 30, 2013
Subsequent Events [Abstract]	'
SUBSEQUENT EVENTS	'
	SUBSEQUENT EVENTS
	In October and November 2013, the Company acquired approximately 9,100 gross (4,800 net) acres prospective for the Wolfcamp and Bone Spring formations in Southeast New Mexico and West Texas and approximately 900 gross (900 net) acres in the Haynesville shale play in Northwest Louisiana. The Company paid approximately $9.7 million to acquire this acreage.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	9 Months Ended
Summary of Significant Accounting Policies (Policies)	Sep. 30, 2013
Accounting Policies [Abstract]	'
Interim Financial Statements, Basis of Presentation, Consolidation and Significant Estimates	'
	Interim Financial Statements, Basis of Presentation, Consolidation and Significant Estimates
	The unaudited condensed consolidated financial statements of Matador and its subsidiaries have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”) but do not include all of the information and footnotes required by generally accepted accounting principles in the United States of America (“U.S. GAAP”) for complete financial statements and should be read in conjunction with the Company’s audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012 filed with the SEC (the “Annual Report”). All intercompany accounts and transactions have been eliminated in consolidation. In management’s opinion, these interim unaudited condensed consolidated financial statements include all adjustments of a normal recurring nature necessary for a fair presentation of the Company’s consolidated financial position as of September 30, 2013, consolidated results of operations for the three and nine months ended September 30, 2013 and 2012, consolidated changes in shareholders’ equity for the nine months ended September 30, 2013 and consolidated cash flows for the nine months ended September 30, 2013 and 2012. Certain reclassifications have been made to prior period items to conform to the current period presentation. These reclassifications had no effect on previously reported results of operations, cash flows or retained earnings. Amounts as of December 31, 2012 are derived from the audited consolidated financial statements in the Annual Report.
	Accounting measurements at interim dates inherently involve greater reliance on estimates than at year end and the results for the interim periods shown in this report are not necessarily indicative of results to be expected for the full year due in part to volatility in oil, natural gas and natural gas liquids prices, global economic and financial market conditions, interest rates, access to sources of liquidity, estimates of reserves, drilling risks, geological risks, transportation restrictions, oil, natural gas and natural gas liquids supply and demand, market competition and interruptions of production.

	The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. These estimates and assumptions may also affect disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company’s consolidated financial statements are based on a number of significant estimates, including accruals for oil and natural gas revenues, accrued assets and liabilities primarily related to oil and natural gas operations, stock-based compensation, valuation of derivative instruments and oil and natural gas reserves. The estimates of oil and natural gas reserves quantities and future net cash flows are the basis for the calculations of depletion and impairment of oil and natural gas properties, as well as estimates of asset retirement obligations and certain tax accruals. While the Company believes its estimates are reasonable, changes in facts and assumptions or the discovery of new information may result in revised estimates. Actual results could differ from these estimates.
Property and Equipment	'
	Property and Equipment
	The Company uses the full-cost method of accounting for its investments in oil and natural gas properties. Under this method of accounting, all costs associated with the acquisition, exploration and development of oil and natural gas properties and reserves, including unproved and unevaluated property costs, are capitalized as incurred and accumulated in a single cost center representing the Company’s activities, which are undertaken exclusively in the United States. Such costs include lease acquisition costs, geological and geophysical expenditures, lease rentals on undeveloped properties, costs of drilling both productive and non-productive wells, capitalized interest on qualifying projects and general and administrative expenses directly related to exploration and development activities, but do not include any costs related to production, selling or general corporate administrative activities. The Company capitalized approximately $2.3 million and $1.7 million of its general and administrative costs for the nine months ended September 30, 2013 and 2012, respectively. The Company capitalized approximately $1.2 million and $1.0 million of its interest expense for the nine months ended September 30, 2013 and 2012, respectively.
	The net capitalized costs of oil and natural gas properties are limited to the lower of unamortized costs less related deferred income taxes or the cost center ceiling, with any excess above the cost center ceiling charged to operations as a full-cost ceiling impairment. The need for a full-cost ceiling impairment is assessed on a quarterly basis. The cost center ceiling is defined as the sum of (a) the present value discounted at 10 percent of future net revenues of proved oil and natural gas reserves, plus (b) unproved and unevaluated property costs not being amortized, plus (c) the lower of cost or estimated fair value of unproved and unevaluated properties included in the costs being amortized, if any, less (d) income tax effects related to the properties involved. Future net revenues from proved non-producing and proved undeveloped reserves are reduced by the estimated costs for developing these reserves. The fair value of the Company’s derivative instruments is not included in the ceiling test computation as the Company does not designate these instruments as hedge instruments for accounting purposes.
	The estimated present value of after-tax future net cash flows from proved oil and natural gas reserves is highly dependent on the commodity prices used in these estimates. These estimates are determined in accordance with guidelines established by the SEC for estimating and reporting oil and natural gas reserves. Under these guidelines, oil and natural gas reserves are estimated using then-current operating and economic conditions, with no provision for price and cost escalations in future periods except by contractual arrangements.
	The commodity prices used to estimate oil and natural gas reserves are based on unweighted, arithmetic averages of first-day-of-the-month oil and natural gas prices for the previous 12-month period. For the period from October 2012 through September 2013, these average oil and natural gas prices were $91.69 per Bbl and $3.605 per MMBtu (million British thermal units), respectively. For the period from October 2011 through September 2012, these average oil and natural gas prices were $91.48 per Bbl and $2.826 per MMBtu, respectively. In estimating the present value of after-tax future net cash flows from proved oil and natural gas reserves, the average oil prices were adjusted by property for quality, transportation and marketing fees and regional price differentials, and the average natural gas prices were adjusted by property for energy content, transportation and marketing fees and regional price differentials. At September 30, 2013 and 2012, the Company’s oil and natural gas reserves estimates were prepared by the Company’s engineering staff in accordance with guidelines established by the SEC and then audited for their reasonableness and conformance with SEC guidelines by Netherland, Sewell & Associates, Inc., independent reservoir engineers.

	Using the average commodity prices, as adjusted, to determine the Company’s estimated proved oil and natural gas reserves at September 30, 2013, the Company’s net capitalized costs less related deferred income taxes did not exceed the full-cost ceiling. As a result, the Company recorded no impairment to its net capitalized costs for the three months ended September 30, 2013. At March 31, 2013, the Company’s net capitalized costs less related deferred income taxes exceeded the full-cost ceiling by $13.7 million. The Company recorded an impairment charge of $21.2 million to its net capitalized costs and a deferred income tax credit of $7.5 million for the three months ended March 31, 2013. These charges are reflected in the Company’s unaudited condensed consolidated statement of operations for the nine months ended September 30, 2013. Using the average commodity prices, as adjusted, to determine the Company’s estimated proved oil and natural gas reserves at June 30, 2012 and September 30, 2012, the Company’s net capitalized costs less related deferred income taxes exceeded the full-cost ceiling by $21.3 million and $2.3 million, respectively. The Company recorded an impairment charge of $33.2 million and $3.6 million to its net capitalized costs and a deferred income tax credit of $11.9 million and $1.3 million, related to the full-cost ceiling limitation at June 30, 2012 and September 30, 2012, respectively. These charges are reflected in the Company's unaudited condensed consolidated statement of operations for the nine months ended September 30, 2012. Changes in oil and natural gas production rates, reserves estimates, future development costs and other factors will determine the Company’s actual ceiling test computation and impairment analyses in future periods.
	As a non-cash item, the full-cost ceiling impairment impacts the accumulated depletion and the net carrying value of the Company’s assets on its consolidated balance sheet, as well as the corresponding consolidated shareholders’ equity, but it has no impact on the Company’s consolidated net cash flows as reported.

	Capitalized costs of oil and natural gas properties are amortized using the unit-of-production method based upon production and estimates of proved reserves quantities. Unproved and unevaluated property costs are excluded from the amortization base used to determine depletion. Unproved and unevaluated properties are assessed for possible impairment on a periodic basis based upon changes in operating or economic conditions. This assessment includes consideration of the following factors, among others: the assignment of proved reserves, geological and geophysical evaluations, intent to drill, remaining lease term and drilling activity and results. Upon impairment, the costs of the unproved and unevaluated properties are immediately included in the amortization base. Dry holes are included in the amortization base immediately upon determination that the well is not productive.
Earnings Per Common Share	'
	Earnings Per Common Share
	The Company reports basic earnings per common share, which excludes the effect of potentially dilutive securities, and diluted earnings per common share, which includes the effect of all potentially dilutive securities, unless their impact is anti-dilutive.
Fair Value Measurements	'
	Fair Value Measurements
	The Company measures and reports certain assets and liabilities on a fair value basis. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). The Company follows Financial Accounting Standards Board (“FASB”) guidance establishing a fair value hierarchy that prioritizes the inputs to valuation methods used to measure fair value.
Recent Accounting Pronouncements	'
	Recent Accounting Pronouncements
	Balance Sheet. In January 2013, the FASB issued Accounting Standards Update, or ASU, 2013-01, Balance Sheet. The ASU clarifies the scope of ASU 2011-11 to limit the application of ASU 2011-11 to derivatives accounted for in accordance with Accounting Standards Codification, or ASC, 815, Derivatives and Hedging, including bifurcated embedded derivatives, repurchase and reverse repurchase agreements, and securities borrowing and securities lending transactions that are either offset in accordance with ASC 210-20-45 or ASC 815-10-45 or subject to an enforceable master netting arrangement or similar agreement. The Company adopted ASU 2013-01 effective January 1, 2013, together with the adoption of ASU 2011-11. The adoption of ASUs 2013-01 and 2011-11 did not have a material effect on the Company’s consolidated financial statements but did require certain additional disclosures (see Note 8).
	Balance Sheet. In December 2011, the FASB issued ASU 2011-11, Balance Sheet. The requirements amend the disclosure requirements related to offsetting in ASC 210-20-50. The amendments require enhanced disclosures by requiring improved information about financial instruments and derivative instruments that are either (1) offset in accordance with either ASC 210-20-45 or ASC 815-10-45 or (2) subject to an enforceable master netting arrangement or similar agreement, irrespective of whether they are offset in accordance with either ASC 210-20-45 or ASC 815-10-45. The Company adopted ASU 2011-11 effective January 1, 2013, together with the adoption of ASU 2013-01. The adoption of ASUs 2011-11 and 2013-01 did not have a material effect on the Company’s consolidated financial statements but did require certain additional disclosures (see Note 8).

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Reconciliations of basic and diluted distributed and undistributed earnings (loss) per common share	'
	The following are reconciliations of the numerators and denominators used to compute the Company’s basic and diluted distributed and undistributed earnings (loss) per common share as reported for the three and nine months ended September 30, 2013 and 2012 (in thousands, except per share data).


		Three Months Ended							Nine Months Ended
		September 30,							September 30,
		2013			2012				2013			2012
	Net income (loss) - numerator
	Net income (loss)	$	20,105		$	(9,197	)		$	29,720		$	(12,073	)

	Less dividends to Class B shareholders - distributed earnings	—			—				—			(28		)

	Undistributed earnings (loss)	$	20,105		$	(9,197	)		$	29,720		$	(12,101	)

	Weighted average common shares outstanding - denominator
	Basic
	Class A	58,016			55,271				55,766			53,379

	Class B	—			—				—			140

	Total	58,016			55,271				55,766			53,519

	Diluted
	Class A
	Weighted average common shares outstanding for basic earnings

	(loss) per share	58,016			55,271				55,766			53,379

	Dilutive effect of options and restricted stock units	136			—				123			—

	Class A weighted average common shares outstanding - diluted	58,152			55,271				55,889			53,379

	Class B
	Weighted average common shares outstanding - no associated

	dilutive shares	—			—				—			140

	Total diluted weighted average common shares outstanding	58,152			55,271				55,889			53,519



		Three Months Ended							Nine Months Ended
		September 30,							September 30,
		2013			2012				2013			2012
	Earnings (loss) per common share
	Basic
	Class A
	Distributed earnings	$	—		$	—			$	—		$	—

	Undistributed earnings (loss)	$	0.35		$	(0.17	)		$	0.53		$	(0.23	)

	Total	$	0.35		$	(0.17	)		$	0.53		$	(0.23	)

	Class B
	Distributed earnings	$	—		$	—			$	—		$	0.2

	Undistributed loss	$	—		$	—			$	—		$	(0.23	)

	Total	$	—		$	—			$	—		$	(0.03	)

	Diluted
	Class A
	Distributed earnings	$	—		$	—			$	—		$	—

Undistributed earnings (loss)	$	0.35		$	(0.17	)		$	0.53		$	(0.23	)

Total	$	0.35		$	(0.17	)		$	0.53		$	(0.23	)

Class B
Distributed earnings	$	—		$	—			$	—		$	0.2

Undistributed loss	$	—		$	—			$	—		$	(0.23	)

Total	$	—		$	—			$	—		$	(0.03	)

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Schedule of changes in Company's asset retirement obligations	'
	The following table summarizes the changes in the Company’s asset retirement obligations for the nine months ended September 30, 2013 (in thousands).



	Beginning asset retirement obligations	$	5,769

	Liabilities incurred during period	417

	Liabilities settled during period	(57		)
	Revisions in estimated cash flows	533

	Accretion expense	248

	Ending asset retirement obligations	6,910

	Less: current asset retirement obligations(1)	(763		)
	Long-term asset retirement obligations	$	6,147

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2013
Open Option Contracts Written [Line Items]	'
Summary of gross asset balances of derivative instruments	'
	The following table presents the gross asset balances of the Company’s derivative financial instruments, the amounts subject to master netting arrangements, the amounts that the Company has presented on a net basis, the amounts subject to master netting across different commodity types that were presented on a gross basis and the location of these balances in its unaudited condensed consolidated balance sheet as of December 31, 2012 (in thousands).


	Derivative Instruments	Gross				Gross amounts				Net amounts of				Amounts subject to master netting arrangements presented on a gross basis
		amounts of				netted in the				assets
		recognized				condensed				presented in the
		assets				consolidated				consolidated
						balance sheet				balance sheet
	Counterparty A
	Current assets	$	6,445			$	(2,373	)		$	4,072			$	—

	Other assets	1,096				(370		)		726				—

	Counterparty B

	Current assets	530				(224		)		306				82

	Other assets	384				(339		)		45				—

	Total	$	8,455			$	(3,306	)		$	5,149			$	82

	The following table presents the gross asset balances of the Company’s derivative financial instruments, the amounts subject to master netting arrangements, the amounts that the Company has presented on a net basis, the amounts subject to master netting across different commodity types that were presented on a gross basis and the location of these balances in its unaudited condensed consolidated balance sheet as of September 30, 2013 (in thousands).


	Derivative Instruments	Gross				Gross amounts				Net amounts of				Amounts subject to master netting arrangements presented on a gross basis
		amounts of				netted in the				assets
		recognized				consolidated				presented in the
		assets				balance sheet				consolidated
										balance sheet
	Counterparty A
	Current assets	$	2,104			$	(2,104	)		$	—			$	—

	Other assets	1,034				(909		)		125				—

	Counterparty B

	Current assets	1,741				(1,289		)		452				138

	Other assets	1,553				(1,039		)		514				—

	Counterparty C

	Current assets	2,874				(2,289		)		585				301

	Other assets	1,478				(1,122		)		356				—

	Total	$	10,784			$	(8,752	)		$	2,032			$	439

Summary of gross liability balances of derivative instruments	'
	The following table presents the gross liability balances of the Company’s derivative financial instruments, the amounts subject to master netting arrangements, the amounts that the Company has presented on a net basis, the amounts subject to master netting across different commodity types that were presented on a gross basis and the location of these balances in its unaudited condensed consolidated balance sheet as of September 30, 2013 (in thousands).


	Derivative Instruments	Gross				Gross amounts				Net amounts of				Amounts subject to master netting arrangements presented on a gross basis
		amounts of				netted in the				liabilities
		recognized				consolidated				presented in the
		liabilities				balance sheet				consolidated
										balance sheet
	Counterparty A
	Current liabilities	$	3,329			$	(2,104	)		$	1,225			$	—

	Long-term liabilities	909				(909		)		—				—

	Counterparty B

	Current liabilities	2,749				(1,289		)		1,460				138

	Long-term liabilities	1,039				(1,039		)		—				—

	Counterparty C

	Current liabilities	3,782				(2,289		)		1,493				301

	Long-term liabilities	1,122				(1,122		)		—				—

	Total	$	12,930			$	(8,752	)		$	4,178			$	439

	The following table presents the gross liability balances of the Company’s derivative financial instruments, the amounts subject to master netting arrangements, the amounts that the Company has presented on a net basis, the amounts subject to master netting across different commodity types that were presented on a gross basis and the location of these balances in its unaudited condensed consolidated balance sheet as of December 31, 2012 (in thousands).



	Derivative Instruments	Gross				Gross amounts				Net amounts of				Amounts subject to master netting arrangements presented on a gross basis
		amounts of				netted in the				liabilities
		recognized				condensed				presented in the
		liabilities				consolidated				condensed
						balance sheet				consolidated
										balance sheet
	Counterparty A
	Current liabilities	$	2,373			$	(2,373	)		$	—			$	—

	Long-term liabilities	370				(370		)		—				—

	Counterparty B

	Current liabilities	894				(224		)		670				82

	Long-term liabilities	339				(339		)		—				—

	Total	$	3,976			$	(3,306	)		$	670			$	82

Summary of location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations	'
	The following table summarizes the location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations for the periods presented (in thousands).



				Three Months Ended								Nine Months Ended
				September 30,								September 30,
	Type of Instrument	Location in Condensed Consolidated Statement of Operations		2013				2012				2013				2012
	Derivative Instrument
	Oil	Revenues: Realized (loss) gain on derivatives		$	(1,519	)		$	374			$	(1,984	)		$	1,093

	Natural Gas	Revenues: Realized gain on derivatives		161				2,996				790				10,053

	NGL’s	Revenues: Realized gain on derivatives		193				1				675				1

	Realized (loss) gain on derivatives			(1,165		)		3,371				(519		)		11,147

	Oil	Revenues: Unrealized loss on derivatives		(8,132		)		(9,053		)		(6,818		)		(7,364		)
	Natural Gas	Revenues: Unrealized gain (loss) on derivatives		57				(3,985		)		(132		)		6,170

	NGL’s	Revenues: Unrealized (loss) gain on derivatives		(1,252		)		45				324				45

	Unrealized loss on derivatives			(9,327		)		(12,993		)		(6,626		)		(1,149		)
	Total			$	(10,492	)		$	(9,622	)		$	(7,145	)		$	9,998

Open costless collar contracts [Member]	'
Open Option Contracts Written [Line Items]	'
Summary of contracts for oil and natural gas	'
	The following is a summary of the Company’s open costless collar contracts for oil and natural gas and open swap contracts for oil and natural gas liquids at September 30, 2013.


	Commodity	Calculation Period		Notional			Price Floor			Price			Fair Value of
				Quantity			($/Bbl)			Ceiling			Asset
				(Bbl/month)						($/Bbl)			(Liability)
													(thousands)
	Oil	10/01/2013 - 12/31/2013		20,000			85			102.25			$	(131	)

	Oil	10/01/2013 - 12/31/2013		20,000			85			108.8			(22		)

	Oil	10/01/2013 - 12/31/2013		20,000			85			110.4			(13		)

	Oil	10/01/2013 - 12/31/2013		20,000			90			102.8			(105		)

	Oil	10/01/2013 - 12/31/2013		20,000			90			115			13

	Oil	10/01/2013 - 06/30/2014		8,000			90			114			101

	Oil	10/01/2013 - 06/30/2014		12,000			90			115.5			163

	Oil	10/01/2013 - 12/31/2014		12,200			85			100.4			(249		)

	Oil	01/01/2014 - 12/31/2014		15,000			85			97.5			(399		)

	Oil	01/01/2014 - 12/31/2014		30,000			85			98			(767		)

	Oil	01/01/2014 - 12/31/2014		12,000			85			100			(154		)

	Oil	01/01/2014 - 12/31/2014		15,000			87			97			(357		)

	Oil	01/01/2014 - 12/31/2014		20,000			88			95.6			(593		)

	Oil	01/01/2014 - 12/31/2014		20,000			90			97			(294		)

	Oil	01/01/2014 - 12/31/2014		12,000			90			97.9			(97		)

	Oil	01/01/2014 - 12/31/2014		15,000			90			97.9			(124		)

	Oil	01/01/2014 - 12/31/2014		15,000			90			98			(135		)

	Oil	01/01/2014 - 12/31/2014		15,000			90			101.15			133

	Total open oil costless collar contracts												(3,030		)


	Commodity	Calculation Period		Notional			Price Floor			Price			Fair Value of
				Quantity			($/MMBtu)			Ceiling			Asset
				(MMBtu/month)						($/MMBtu)			(Liability)
													(thousands)
	Natural Gas	10/01/2013 - 12/31/2013		100,000			3			3.83			(16	)

	Natural Gas	10/01/2013 - 12/31/2013		100,000			3			4.95			1

	Natural Gas	10/01/2013 - 12/31/2013		100,000			3			4.96			1

	Natural Gas	10/01/2013 - 12/31/2013		150,000			3			4.24			(5	)

	Natural Gas	10/01/2013 - 12/31/2013		100,000			3.25			4.41			3

	Natural Gas	10/01/2013 - 12/31/2013		100,000			3.25			4.44			3

	Natural Gas	10/01/2013 - 12/31/2013		100,000			3.5			4.37			15

Natural Gas	10/01/2013 - 12/31/2013		80,000			3.75			4.57			54

Natural Gas	01/01/2014 - 12/31/2014		100,000			3			5.15			(2	)

Natural Gas	01/01/2014 - 12/31/2014		100,000			3.25			5.21			59

Natural Gas	01/01/2014 - 12/31/2014		100,000			3.25			5.22			60

Natural Gas	01/01/2014 - 12/31/2014		100,000			3.25			5.37			76

Natural Gas	01/01/2014 - 12/31/2014		100,000			3.25			5.42			79

Natural Gas	01/01/2014 - 12/31/2014		100,000			3.5			4.9			118

Natural Gas	01/01/2014 - 12/31/2014		100,000			3.75			4.77			227

Natural Gas	01/01/2015 - 12/31/2015		200,000			3.75			5.04			331

Total open natural gas costless collar contracts												1,004

Open Swap Contracts [Member]	'
Open Option Contracts Written [Line Items]	'
Summary of contracts for oil and natural gas	'


	Commodity	Calculation Period		Notional Quantity			Fixed Price			Fair Value of
				(Bbl/month)			($/Bbl)			Liability
										(thousands)
	Oil	10/01/2013 - 12/31/2013		10,000			90.2			(341	)

	Oil	10/01/2013 - 12/31/2013		10,000			90.65			(327	)

	Total open oil swap contracts									(668	)


	Commodity	Calculation Period		Notional Quantity			Fixed Price			Fair Value of Asset (Liability)
				(Gal/month)			($/Gal)			(thousands)
	Purity Ethane	10/01/2013 - 12/31/2013		110,000			0.335			28

	Purity Ethane	10/01/2013 - 12/31/2013		110,000			0.355			35

	Propane	10/01/2013 - 12/31/2013		53,000			0.953			(20		)

	Propane	10/01/2013 - 12/31/2013		106,000			0.96			(37		)

	Propane	10/01/2013 - 12/31/2013		53,000			1.001			(12		)

	Propane	10/01/2013 - 12/31/2013		150,000			1.103			16

	Propane	01/01/2014 - 12/31/2014		116,000			0.95			(87		)

	Propane	01/01/2014 - 12/31/2014		116,000			1.003			8

	Propane	01/01/2014 - 12/31/2014		60,000			1.015			13

	Normal Butane	10/01/2013 - 12/31/2013		14,700			1.455			3

	Normal Butane	10/01/2013 - 12/31/2013		14,700			1.56			8

	Normal Butane	10/01/2013 - 12/31/2013		21,000			1.575			12

	Normal Butane	10/01/2013 - 12/31/2013		117,000			1.575			63

	Normal Butane	01/01/2014 - 12/31/2014		17,500			1.54			57

	Normal Butane	01/01/2014 - 12/31/2014		45,500			1.55			143

	Isobutane	10/01/2013 - 12/31/2013		7,000			1.515			2

	Isobutane	10/01/2013 - 12/31/2013		7,000			1.625			4

	Isobutane	10/01/2013 - 12/31/2013		43,500			1.675			34

	Isobutane	10/01/2013 - 12/31/2013		23,000			1.675			18

	Isobutane	01/01/2014 - 12/31/2014		22,000			1.64			87

	Isobutane	01/01/2014 - 12/31/2014		37,000			1.64			156

	Natural Gasoline	10/01/2013 - 12/31/2013		12,000			2.025			(3		)

	Natural Gasoline	10/01/2013 - 12/31/2013		12,000			2.085			—

	Natural Gasoline	10/01/2013 - 12/31/2013		12,000			2.102			—

	Natural Gasoline	10/01/2013 - 12/31/2013		36,000			2.105			1

Natural Gasoline	10/01/2013 - 12/31/2013		90,500			2.148			20

Natural Gasoline	01/01/2014 - 12/31/2014		30,000			1.97			(7		)

Natural Gasoline	01/01/2014 - 12/31/2014		41,000			2			6

Total open NGL swap contracts									548

Total open derivative financial instruments									$	(2,146	)

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Summary of the valuation of the Company's financial assets and liabilities that were accounted for at fair value on a recurring basis	'
	The following tables summarize the valuation of the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis in accordance with the classifications provided above as of September 30, 2013 and December 31, 2012 (in thousands).


		Fair Value Measurements at
		September 30, 2013 using
	Description	Level 1		Level 2			Level 3			Total
	Assets (Liabilities)
	Certificates of deposit	$	—	$	40		$	—		$	40

	Oil, natural gas and NGL derivatives	—		2,032			—			2,032

	Oil, natural gas and NGL derivatives	—		(4,178		)	—			(4,178		)

	Total	$	—	$	(2,106	)	$	—		$	(2,106	)



		Fair Value Measurements at
		December 31, 2012 using
	Description	Level 1		Level 2			Level 3			Total
	Assets (Liabilities)
	Certificates of deposit	$	—	$	230		$	—		$	230

	Oil, natural gas and NGL derivatives	—		5,149			—			5,149

	Oil, natural gas and NGL derivatives	—		(670		)	—			(670		)

	Total	$	—	$	4,709		$	—		$	4,709

Additions to asset retirement obligations and lease and well equipment inventory at fair value on a non-recurring basis	'
	The following tables summarize the valuation of the Company’s assets and liabilities that were accounted for at fair value on a non-recurring basis for the periods ended September 30, 2013 and December 31, 2012 (in thousands).


		Fair Value Measurements at
		September 30, 2013 using
	Description	Level 1		Level 2			Level 3			Total
	Assets (Liabilities)
	Asset retirement obligations	$	—	$	—		$	(951	)	$	(951	)

	Total	$	—	$	—		$	(951	)	$	(951	)



		Fair Value Measurements at
		December 31, 2012 using
	Description	Level 1		Level 2			Level 3			Total
	Assets (Liabilities)
	Asset retirement obligations	$	—	$	—		$	(1,243	)	$	(1,243	)

	Lease and well equipment inventory	—		—			34			34

	Total	$	—	$	—		$	(1,209	)	$	(1,209	)

Supplemental_Disclosures_Table

Supplemental Disclosures (Tables)	9 Months Ended
	Sep. 30, 2013
Supplemental Disclosures [Abstract]	'
Summary of current accrued liabilities	'
	The following table summarizes the Company’s current accrued liabilities at September 30, 2013 and December 31, 2012 (in thousands).



		September 30,			December 31,
		2013			2012
	Accrued evaluated and unproved and unevaluated property costs	$	38,879		$	45,592

	Accrued support equipment and facilities costs	228			1,382

	Accrued cost to issue equity	456			—

	Accrued stock-based compensation	—			65

	Accrued lease operating expenses	5,656			5,218

	Accrued interest on borrowings under Credit Agreement	117			255

	Accrued asset retirement obligations	763			660

	Accrued partners’ share of joint interest charges	890			3,597

	Other	3,059			2,410

	Total accrued liabilities	$	50,048		$	59,179

Supplemental disclosures of cash flow information	'
	The following table provides supplemental disclosures of cash flow information for the nine months ended September 30, 2013 and 2012 (in thousands).


		Nine Months Ended
		September 30,
		2013			2012
	Cash paid for interest expense, net of amounts capitalized	$	2,110		$	442

	Asset retirement obligations related to mineral properties	889			405

	Asset retirement obligations related to support equipment and facilities	4			54

	(Decrease) increase in liabilities for oil and natural gas properties capital expenditures	(6,288		)	19,067

	(Decrease) increase in liabilities for support equipment and facilities	(1,100		)	482

	Increase (decrease) in liabilities for accrued cost to issue equity	456			(332		)

	Issuance of restricted stock units for Board and advisor services	186			34

	Issuance of common stock for advisor services	25			71

	Stock-based compensation expense recognized as liability	715			(930		)

	Transfer of inventory from oil and natural gas properties	201			(91		)

Nature_of_Operations_Details

Nature of Operations (Details)	Sep. 30, 2013
Nature of Operations (Details)	subsidiary
Nature of Operations (Textual) [Abstract]	'
Number of wholly owned subsidiaries	4

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Net income (loss) - numerator	'	'	'	'
Net (loss) income	$20,105	($9,197)	$29,720	($12,073)
Less dividends to Class B shareholders - distributed earnings	'	0	0	-28
Undistributed (loss) earnings	$20,105	($9,197)	$29,720	($12,101)
Weighted average common shares outstanding - denominator	'	'	'	'
Weighted average common shares outstanding for basic earnings (loss) per share	58,016	55,271	55,766	53,519
Weighted average common shares outstanding - Diluted	58,152	55,271	55,889	53,519
Class A [Member]	'	'	'	'
Weighted average common shares outstanding - denominator	'	'	'	'
Weighted average common shares outstanding for basic earnings (loss) per share	58,016	55,271	55,766	53,379
Dilutive effect of options and restricted stock units	136	0	123	0
Weighted average common shares outstanding - Diluted	58,152	55,271	55,889	53,379
Basic	'	'	'	'
Distributed earnings	$0	$0	$0	$0
Undistributed (loss) earnings	$0.35	($0.17)	$0.53	($0.23)
Total	$0.35	($0.17)	$0.53	($0.23)
Diluted	'	'	'	'
Distributed earnings	'	'	$0	'
Undistributed (loss) earnings	$0.35	($0.17)	$0.53	($0.23)
Total	$0.35	($0.17)	$0.53	($0.23)
Class B [Member]	'	'	'	'
Weighted average common shares outstanding - denominator	'	'	'	'
Weighted average common shares outstanding for basic earnings (loss) per share	0	0	0	140
Weighted average common shares outstanding - Diluted	0	0	0	140
Basic	'	'	'	'
Distributed earnings	$0	$0	$0	$0.20
Undistributed (loss) earnings	$0	$0	$0	($0.23)
Total	$0	$0	$0	($0.03)
Diluted	'	'	'	'
Distributed earnings	$0	$0	$0	$0.20
Undistributed (loss) earnings	$0	$0	$0	($0.23)
Total	$0	$0	$0	($0.03)

Summary_of_Significant_Account4

Summary of Significant Accounting Policies (Details Textual) (USD $)	1 Months Ended	3 Months Ended				9 Months Ended		12 Months Ended
	Sep. 30, 2012	Sep. 30, 2013	Jun. 30, 2013	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'	'	'	'	'
Income Tax Expense Recorded	'	'	'	'	'	$0	'	'	'
Summary of Significant Accounting Policies (Textual) [Abstract]	'	'	'	'	'	'	'	'	'
Dividends paid	'	'	'	'	'	0	96,000	'	'
Summary of Significant Accounting Policies (Additional Textual) [Abstract]	'	'	'	'	'	'	'	'	'
Capitalized general and administrative costs	'	'	'	'	'	2,300,000	1,700,000	'	'
Capitalized interest expense	1,000,000	'	'	'	'	-1,200,000	'	'	'
Present value discounted percent of future net revenues of proved oil and natural gas reserves	'	'	'	'	'	10.00%	'	'	'
Average oil and natural gas prices	'	'	'	'	'	'	'	91.69	91.48
Net capitalized costs less related deferred income taxes exceeded the full-cost ceiling	'	'	13,700,000	2,300,000	21,300,000	'	'	'	'
Impairment charge of net capitalized costs	'	0	21,229,000	3,596,000	33,200,000	21,229,000	36,801,000	'	'
Deferred income tax credit	'	'	7,500,000	1,300,000	11,900,000	'	'	'	'
Dividends declared	'	'	'	'	'	0	27,643	'	'
Stock Options [Member]	'	'	'	'	'	'	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'	'	'	'	'	'	'	'
Total options to purchase shares of the Company's common stock and restricted stock excluded from the calculations	'	1,085,152	'	'	'	1,293,568	'	'	'
Restricted stock [Member]	'	'	'	'	'	'	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'	'	'	'	'	'	'	'
Total options to purchase shares of the Company's common stock and restricted stock excluded from the calculations	'	'	'	233,349	'	139,963	231,683	'	'
Class A [Member]	'	'	'	'	'	'	'	'	'
Summary of Significant Accounting Policies (Textual) [Abstract]	'	'	'	'	'	'	'	'	'
Dividends paid	'	'	'	'	'	0	'	'	'
Initial public offering	'	'	'	'	'	1,030,700	'	'	'
Class B [Member]	'	'	'	'	'	'	'	'	'
Summary of Significant Accounting Policies (Textual) [Abstract]	'	'	'	'	'	'	'	'	'
Total dividend paid	'	'	'	'	$96,356	'	'	'	'
Class B [Member] \| Maximum [Member]	'	'	'	'	'	'	'	'	'
Summary of Significant Accounting Policies (Textual) [Abstract]	'	'	'	'	'	'	'	'	'
Cumulative annual dividends per share rate	'	$0.66	'	'	'	'	'	'	'
Class B [Member] \| Minimum [Member]	'	'	'	'	'	'	'	'	'
Summary of Significant Accounting Policies (Textual) [Abstract]	'	'	'	'	'	'	'	'	'
Cumulative annual dividends per share rate	'	$0.26	'	'	'	'	'	'	'

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	3 Months Ended			9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012	Sep. 30, 2013		Sep. 30, 2012	Dec. 31, 2012
Changes in the Company's asset retirement obligations	'		'	'		'	'
Beginning asset retirement obligations	'		'	$5,769		'	'
Liabilities incurred during period	'		'	417		'	'
Liabilities settled during period	'		'	-57		'	'
Revisions in estimated cash flows	'		'	533		'	'
Accretion expense	86		59	248		170	'
Ending asset retirement obligations	6,910		'	6,910		'	'
Less: current asset retirement obligations	-763	[1]	'	-763	[1]	'	'
Long-term asset retirement obligations	$6,147		'	$6,147		'	$5,109

[1]	Included in accrued liabilities in the Companybs unaudited condensed consolidated balance sheet at SeptemberB 30, 2013.

Revolving_Credit_Agreement_Det

Revolving Credit Agreement (Details) (USD $)

3 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

3 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Sep. 12, 2013

Dec. 20, 2012

Sep. 30, 2012

Sep. 27, 2012

Nov. 07, 2013

Oct. 09, 2013

Aug. 07, 2013

Sep. 30, 2013

Jun. 04, 2013

Sep. 28, 2012

Sep. 30, 2013

Jun. 04, 2013

Dec. 20, 2012

Sep. 30, 2013

Second amended credit agreement [Member]

Third amended credit agreement [Member]

Subsequent Event [Member]

Base rate loan [Member]

LIBOR rate [Member]

Eurodollar Loan [Member]

Minimum [Member]

Maximum [Member]

Base rate loan [Member]

Eurodollar Loan [Member]

Base rate loan [Member]

Eurodollar Loan [Member]

Revolving Credit Agreement (Textual) [Abstract]

Company amended and restated its senior secured revolving credit agreement

'2012-09-28

Senior secured revolving credit maximum facility

$400

$350

Borrowing base

275

255

500

280

215

Conforming borrowing base

220

Covenant, additional indebtedness

Borrowed under credit agreement

145

160

Additional borrowings for working capital requirements

Outstanding letters of credit

0.3

Borrowings interest rate

1.00%

Additional interest rate

0.0075

0.0175

0.03

0.04

Credit facility fee

0.38%

0.50%

Borrowings interest rate description

'If the Company borrows funds as a base rate loan, such borrowings will bear interest at a rate equal to the higher of (i)B the prime rate for such day or (ii)B the Federal Funds Effective Rate on such day, plus 0.50% or (iii)B the daily adjusting LIBOR rate plus 1.0% plus, in each case, an amount from 0.75% to 3.00% of such outstanding loan depending on the level of borrowings under the agreement.

' If the Company borrows funds as a Eurodollar loan, such borrowings will bear interest at a rate equal to (i)B the quotient obtained by dividing (A)B the LIBOR rate by (B)B a percentage equal to 100% minus the maximum rate during such interest calculation period at which RBC is required to maintain reserves on Eurocurrency Liabilities (as defined in Regulation D of the Board of Governors of the Federal Reserve System) plus (ii)B an amount from 1.75% to 4.00% of such outstanding loan depending on the level of borrowings under the Credit Agreement.

Revolving Credit Agreement (Additional Textual) [Abstract]

Credit Agreement, maturity date

29-Dec-16

The borrowing base under the Credit Agreement determined

'semi-annually

Repay deficit in agreement Period

'6 months

Additional deferred loan cost

1.1

Deferred loan costs

2.3

Outstanding borrowings bore interest effective rate

4.00%

Federal Funds Effective Plus Rate

0.50%

Percentage of reserves required to maintain

100.00%

Current ratio

Total debt outstanding to EBITDA

Line of Credit Facility, Decrease, Repayments

$130

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended	9 Months Ended
Income Taxes (Details) (USD $)	Sep. 30, 2013	Sep. 30, 2013
Income Tax Disclosure [Abstract]	'	'
Effective Income Tax Rate, Continuing Operations	0.00%	0.00%
Income Taxes (Textual) [Abstract]	'	'
Company established valuation allowance	'	$6,700,000
Income tax expense recorded	'	$0

StockBased_Compensation_Detail

Stock-Based Compensation (Details) (USD $)	1 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2013	Feb. 28, 2013
Stock-Based Compensation (Textual) [Abstract]	'	'
Option granted to purchase shares of its common stock, Exercise price one	507,500	'
Option granted to purchase shares of its common stock, Exercise price two	284,292	'
Granted option share purchase price, per share Exercise price one	$8.21	'
Granted option share purchase price, per share Exercise price two	$8.18	'
Grant date fair value, Option grants during period	$2.80	'
Number of options, Options forfeited (in shares)	'	408,000
Options expired unexercised or were forfeited, share price	'	$10
Minimum [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Vesting period of shares	'3 years	'
Maximum [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Vesting period of shares	'4 years	'
Restricted stock [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Restricted stock grants during period	324,771	'
Grant date fair value, Total fair value	$2.40	'

Derivative_Financial_Instrumen2

Derivative Financial Instruments (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013
Summary of contracts for oil and natural gas	'
Fair Value of Asset (Liability)	($2,146)
Open costless collar contracts [Member] \| Oil [Member]	'
Summary of contracts for oil and natural gas	'
Fair Value of Asset (Liability)	-3,030
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 20,000 Notional Amount, 85 Price Floor, 102.25 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	20,000
Price Floor	85
Price Ceiling	102
Fair Value of Asset (Liability)	-131
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 20,000 Notional Amount, 85 Price Floor, 108.80 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	20,000
Price Floor	85
Price Ceiling	109
Fair Value of Asset (Liability)	-22
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 20,000 Notional Amount, 85 Price Floor, 110.40 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	20,000
Price Floor	85
Price Ceiling	110
Fair Value of Asset (Liability)	-13
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 20,000 Notional Amount, 90 Price Floor, 102.80 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	20,000
Price Floor	90
Price Ceiling	103
Fair Value of Asset (Liability)	-105
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 20,000 Notional Amount, 90 Price Floor, 115 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	20,000
Price Floor	90
Price Ceiling	115
Fair Value of Asset (Liability)	13
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 8,000 Notional Amount, 90 Price Floor, 114 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 06/30/2014
Notional Quantity	8,000
Price Floor	90
Price Ceiling	114
Fair Value of Asset (Liability)	101
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 12,000 Notional Amount, 90 Price Floor, 115.50 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 06/30/2014
Notional Quantity	12,000
Price Floor	90
Price Ceiling	116
Fair Value of Asset (Liability)	163
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 12,200 Notional Amount, 85 Price Floor, 100.40 Price Ceiling [Member] [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2014
Notional Quantity	12,200
Price Floor	85
Price Ceiling	100
Fair Value of Asset (Liability)	-249
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 15,000 Notional Amount, 85 Price Floor, 97.50 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	15,000
Price Floor	85
Price Ceiling	97.5
Fair Value of Asset (Liability)	-399
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 30,000 Notional Amount, 85 Price Floor, 98 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	30,000
Price Floor	85
Price Ceiling	98
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 12,000 Notional Amount, 85 Price Floor, 100 Price Ceiling [Member] [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	12,000
Price Floor	85
Price Ceiling	100
Fair Value of Asset (Liability)	-767
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 15,000 Notional Amount, 87 Price Floor, 97 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	15,000
Price Floor	87
Price Ceiling	97
Fair Value of Asset (Liability)	-357
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 20,000 Notional Amount, 88 Price Floor, 95.60 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	20,000
Price Floor	88
Price Ceiling	95.6
Fair Value of Asset (Liability)	-593
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 20,000 Notional Amount, 90 Price Floor, 97 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	20,000
Price Floor	90
Price Ceiling	97
Fair Value of Asset (Liability)	-294
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 12,000 Notional Amount, 90 Price Floor, 97.90 Price Ceiling [Member] [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	12,000
Price Floor	90
Price Ceiling	97.9
Fair Value of Asset (Liability)	-97
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 15,000 Notional Amount, 90 Price Floor, 97.90 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	15,000
Price Floor	90
Price Ceiling	97.9
Fair Value of Asset (Liability)	-124
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 15,000 Notional Amount, 90 Price Floor, 98 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Notional Quantity	15,000
Price Floor	90
Price Ceiling	98
Fair Value of Asset (Liability)	-135
Open costless collar contracts [Member] \| Oil [Member] \| Open Oil Collar Contract, 15,000 Notional Amount, 90 Price Floor, 101.15 Price Ceiling [Member] [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	15,000
Price Floor	90
Price Ceiling	101
Fair Value of Asset (Liability)	133
Open costless collar contracts [Member] \| Open Oil Collar Contract, 12,200 Notional Amount, 85 Price Floor, 100.40 Price Ceiling [Member] [Member] \| Open Oil Collar Contract, 12,000 Notional Amount, 85 Price Floor, 100 Price Ceiling [Member] [Member]	'
Summary of contracts for oil and natural gas	'
Fair Value of Asset (Liability)	-154
Open costless collar contracts [Member] \| Natural Gas [Member]	'
Summary of contracts for oil and natural gas	'
Fair Value of Asset (Liability)	1,004
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3 Price Floor, 3.83 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	100,000
Price Floor	3
Price Ceiling	3.83
Fair Value of Asset (Liability)	-16
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3 Price Floor, 4.95 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	100,000
Price Floor	3
Price Ceiling	4.95
Fair Value of Asset (Liability)	1
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3 Price Floor, 4.96 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	100,000
Price Floor	3
Price Ceiling	4.96
Fair Value of Asset (Liability)	1
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 150,000 Notional Amount, 3 Price Floor, 4.24 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	150,000
Price Floor	3
Price Ceiling	4.24
Fair Value of Asset (Liability)	-5
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3.25 Price Floor, 4.41 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	100,000
Price Floor	3.25
Price Ceiling	4.41
Fair Value of Asset (Liability)	3
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3.25 Price Floor, 4.44 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	100,000
Price Floor	3.25
Price Ceiling	4.44
Fair Value of Asset (Liability)	3
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3.50 Price Floor, 4.37 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	100,000
Price Floor	3.5
Price Ceiling	4.37
Fair Value of Asset (Liability)	15
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 80,000 Notional Amount, 3.75 Price Floor, 4.57 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	80,000
Price Floor	3.75
Price Ceiling	4.57
Fair Value of Asset (Liability)	54
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3 Price Floor, 5.15 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	100,000
Price Floor	3
Price Ceiling	5.15
Fair Value of Asset (Liability)	-2
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3.25 Price Floor, 5.21 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	100,000
Price Floor	3.25
Price Ceiling	5.21
Fair Value of Asset (Liability)	59
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3.25 Price Floor, 5.22 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	100,000
Price Floor	3.25
Price Ceiling	5.22
Fair Value of Asset (Liability)	60
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3.25 Price Floor, 5.37 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	100,000
Price Floor	3.25
Price Ceiling	5.37
Fair Value of Asset (Liability)	76
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3.25 Price Floor, 5.42 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	100,000
Price Floor	3.25
Price Ceiling	5.42
Fair Value of Asset (Liability)	79
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3.50 Price Floor, 4.90 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	100,000
Price Floor	3.5
Price Ceiling	4.9
Fair Value of Asset (Liability)	118
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 100,000 Notional Amount, 3.75 Price Floor, 4.77 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	100,000
Price Floor	3.75
Price Ceiling	4.77
Fair Value of Asset (Liability)	227
Open costless collar contracts [Member] \| Natural Gas [Member] \| Open Natural Gas Collar Contract, 200,000 Notional Amount, 3.75 Price Floor, 5.04 Price Ceiling [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'01/01/2015 - 12/31/2015
Notional Quantity	200,000
Price Floor	3.75
Price Ceiling	5.04
Fair Value of Asset (Liability)	331
Open Swap Contracts [Member] \| Oil [Member]	'
Summary of contracts for oil and natural gas	'
Fair Value of Asset (Liability)	-668
Open Swap Contracts [Member] \| Oil [Member] \| Open Oil Swap Contract, 10,000 Notional Amount, 90.20 Fixed Price [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	10,000
Price Floor	90.2
Fair Value of Asset (Liability)	-341
Open Swap Contracts [Member] \| Oil [Member] \| Open Oil Swap Contract, 10,000 Notional Amount, 90.65 Fixed Price [Member]	'
Summary of contracts for oil and natural gas	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	10,000
Price Floor	90.65
Fair Value of Asset (Liability)	($327)

Derivative_Financial_Instrumen3

Derivative Financial Instruments (Details 1) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013
Open swap contracts for natural gas liquid	'
Fair Value of Asset (Liability)	($2,146)
NGL's [Member] \| Open Swap Contract [Member]	'
Open swap contracts for natural gas liquid	'
Fair Value of Asset (Liability)	548
NGL's [Member] \| Open Swap Contract [Member] \| NGL Purity Ethane Swap Contract, 110,000 Notional Amount, 0.335 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	110,000
Fixed Price	0.335
Fair Value of Asset (Liability)	28
NGL's [Member] \| Open Swap Contract [Member] \| NGL Purity Ethane Swap Contract, 110,000 Notional Amount, 0.355 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	110,000
Fixed Price	0.355
Fair Value of Asset (Liability)	35
NGL's [Member] \| Open Swap Contract [Member] \| NGL Propane Swap Contract, 53,000 Notional Amount, 0.953 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	53,000
Fixed Price	0.953
Fair Value of Asset (Liability)	-20
NGL's [Member] \| Open Swap Contract [Member] \| NGL Propane Swap Contract, 106,000 Notional Amount, 0.960 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	106,000
Fixed Price	0.96
Fair Value of Asset (Liability)	-37
NGL's [Member] \| Open Swap Contract [Member] \| NGL Propane Swap Contract, 53,000 Notional Amount, 1.001 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	53,000
Fixed Price	1.001
Fair Value of Asset (Liability)	-12
NGL's [Member] \| Open Swap Contract [Member] \| NGL Propane Swap Contract, 150,000 Notional Amount, 1.103 Fixed Price [Member] [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	150,000
Fixed Price	1.103
Fair Value of Asset (Liability)	16
NGL's [Member] \| Open Swap Contract [Member] \| NGL Propane Swap Contract, 116,000 Notional Amount, 0.950 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	116,000
Fixed Price	0.95
Fair Value of Asset (Liability)	-87
NGL's [Member] \| Open Swap Contract [Member] \| NGL Propane Swap Contract, 116,000 Notional Amount, 1.003 Fixed Price [Member] [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	116,000
Fixed Price	1.0025
Fair Value of Asset (Liability)	8
NGL's [Member] \| Open Swap Contract [Member] \| NGL Propane Swap Contract, 60,000 Notional Amount, 1.015 Fixed Price [Member] [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	60,000
Fixed Price	1.015
Fair Value of Asset (Liability)	13
NGL's [Member] \| Open Swap Contract [Member] \| NGL Normal Butane Swap Contract, 14,700 Notional Amount, 1.455 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	14,700
Fixed Price	1.455
Fair Value of Asset (Liability)	3
NGL's [Member] \| Open Swap Contract [Member] \| NGL Normal Butane Swap Contract, 14,700 Notional Amount, 1.560 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	14,700
Fixed Price	1.56
Fair Value of Asset (Liability)	8
NGL's [Member] \| Open Swap Contract [Member] \| NGL Normal Butane Swap Contract, 21,000 Notional Amount, 1.575 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	21,000
Fixed Price	1.575
Fair Value of Asset (Liability)	12
NGL's [Member] \| Open Swap Contract [Member] \| NGL Normal Butane Swap Contract, 117,000 Notional Amount, 1.575 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	117,000
Fixed Price	1.575
Fair Value of Asset (Liability)	63
NGL's [Member] \| Open Swap Contract [Member] \| NGL Normal Butane Swap Contract, 17,500 Notional Amount, 1.540 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	17,500
Fixed Price	1.54
Fair Value of Asset (Liability)	57
NGL's [Member] \| Open Swap Contract [Member] \| NGL Normal Butane Swap Contract, 45,500 Notional Amount, 1.550 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	45,500
Fixed Price	1.55
Fair Value of Asset (Liability)	143
NGL's [Member] \| Open Swap Contract [Member] \| NGL Isobutane Swap Contract, 7,000 Notional Amount, 1.515 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	7,000
Fixed Price	1.515
Fair Value of Asset (Liability)	2
NGL's [Member] \| Open Swap Contract [Member] \| NGL Isobutane Swap Contract, 7,000 Notional Amount, 1.625 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	7,000
Fixed Price	1.625
Fair Value of Asset (Liability)	4
NGL's [Member] \| Open Swap Contract [Member] \| NGL Isobutane Swap Contract, 43,000 Notional Amount, 1.675 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	43,500
Fixed Price	1.675
Fair Value of Asset (Liability)	34
NGL's [Member] \| Open Swap Contract [Member] \| NGL Isobutane Swap Contract, 23,000 Notional Amount, 1.675 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	23,000
Fixed Price	1.675
Fair Value of Asset (Liability)	18
NGL's [Member] \| Open Swap Contract [Member] \| NGL Isobutane Swap Contract, 22,000 Notional Amount, 1.640 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	22,000
Fixed Price	1.64
Fair Value of Asset (Liability)	87
NGL's [Member] \| Open Swap Contract [Member] \| NGL Isobutane Swap Contract, 37,000 Notional Amount, 1.640 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	37,000
Fixed Price	1.64
Fair Value of Asset (Liability)	156
NGL's [Member] \| Open Swap Contract [Member] \| NGL Natural Gasoline Swap Contract, 12,000 Notional Amount, 2.025 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	12,000
Fixed Price	2.025
Fair Value of Asset (Liability)	-3
NGL's [Member] \| Open Swap Contract [Member] \| NGL Natural Gasoline Swap Contract, 12,000 Notional Amount, 2.085 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	12,000
Fixed Price	2.085
Fair Value of Asset (Liability)	0
NGL's [Member] \| Open Swap Contract [Member] \| NGL Natural Gasoline Swap Contract, 12,000 Notional Amount, 2.102 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	12,000
Fixed Price	2.102
Fair Value of Asset (Liability)	0
NGL's [Member] \| Open Swap Contract [Member] \| NGL Natural Gasoline Swap Contract, 36,000 Notional Amount, 2.105 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	36,000
Fixed Price	2.105
Fair Value of Asset (Liability)	1
NGL's [Member] \| Open Swap Contract [Member] \| NGL Natural Gasoline Swap Contract, 90,500 Notional Amount, 2.148 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'10/01/2013 - 12/31/2013
Notional Quantity	90,500
Fixed Price	2.148
Fair Value of Asset (Liability)	20
NGL's [Member] \| Open Swap Contract [Member] \| NGL Natural Gasoline Swap Contract, 30,000 Notional Amount, 1.970 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	30,000
Fixed Price	1.97
Fair Value of Asset (Liability)	-7
NGL's [Member] \| Open Swap Contract [Member] \| NGL Natural Gasoline Swap Contract, 41,000 Notional Amount, 2.000 Fixed Price [Member]	'
Open swap contracts for natural gas liquid	'
Calculation Period	'01/01/2014 - 12/31/2014
Notional Quantity	41,000
Fixed Price	2
Fair Value of Asset (Liability)	$6

Derivative_Financial_Instrumen4

Derivative Financial Instruments (Details 2) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Summary of gross asset balances of derivative instruments	'	'
Gross amounts of recognized assets	$10,784	$8,455
Gross amounts netted in the consolidated balance sheet	-8,752	-3,306
Net amounts of assets presented in the condensed consolidated balance sheet	2,032	5,149
Amounts subject to master netting arrangements presented on a gross basis	439	82
Counterparty A [Member] \| Current Assets [Member]	'	'
Summary of gross asset balances of derivative instruments	'	'
Gross amounts of recognized assets	2,104	6,445
Gross amounts netted in the consolidated balance sheet	-2,104	-2,373
Net amounts of assets presented in the condensed consolidated balance sheet	0	4,072
Counterparty A [Member] \| Other assets [Member]	'	'
Summary of gross asset balances of derivative instruments	'	'
Gross amounts of recognized assets	1,034	1,096
Gross amounts netted in the consolidated balance sheet	-909	-370
Net amounts of assets presented in the condensed consolidated balance sheet	125	726
Counterparty B [Member] \| Current Assets [Member]	'	'
Summary of gross asset balances of derivative instruments	'	'
Gross amounts of recognized assets	1,741	530
Gross amounts netted in the consolidated balance sheet	-1,289	-224
Net amounts of assets presented in the condensed consolidated balance sheet	452	306
Amounts subject to master netting arrangements presented on a gross basis	138	82
Counterparty B [Member] \| Other assets [Member]	'	'
Summary of gross asset balances of derivative instruments	'	'
Gross amounts of recognized assets	1,553	384
Gross amounts netted in the consolidated balance sheet	-1,039	-339
Net amounts of assets presented in the condensed consolidated balance sheet	514	45
Counterparty C [Member] \| Current Assets [Member]	'	'
Summary of gross asset balances of derivative instruments	'	'
Gross amounts of recognized assets	2,874	'
Gross amounts netted in the consolidated balance sheet	-2,289	'
Net amounts of assets presented in the condensed consolidated balance sheet	585	'
Amounts subject to master netting arrangements presented on a gross basis	301	'
Counterparty C [Member] \| Other assets [Member]	'	'
Summary of gross asset balances of derivative instruments	'	'
Gross amounts of recognized assets	1,478	'
Gross amounts netted in the consolidated balance sheet	-1,122	'
Net amounts of assets presented in the condensed consolidated balance sheet	$356	'

Derivative_Financial_Instrumen5

Derivative Financial Instruments (Details 3) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Summary of gross liability balances of derivative instruments	'	'
Gross amounts of recognized liabilities	$12,930	$3,976
Gross amounts netted in the consolidated balance sheet	-8,752	-3,306
Net amounts of liabilities presented in the condensed consolidated balance sheet	4,178	670
Amounts subject to master netting arrangements presented on a gross basis	439	82
Counterparty A [Member] \| Current liabilities [Member]	'	'
Summary of gross liability balances of derivative instruments	'	'
Gross amounts of recognized liabilities	3,329	2,373
Gross amounts netted in the consolidated balance sheet	-2,104	-2,373
Net amounts of liabilities presented in the condensed consolidated balance sheet	1,225	0
Counterparty A [Member] \| Long-term liabilities [Member]	'	'
Summary of gross liability balances of derivative instruments	'	'
Gross amounts of recognized liabilities	909	370
Gross amounts netted in the consolidated balance sheet	-909	-370
Net amounts of liabilities presented in the condensed consolidated balance sheet	0	0
Counterparty B [Member] \| Current liabilities [Member]	'	'
Summary of gross liability balances of derivative instruments	'	'
Gross amounts of recognized liabilities	2,749	894
Gross amounts netted in the consolidated balance sheet	-1,289	-224
Net amounts of liabilities presented in the condensed consolidated balance sheet	1,460	670
Counterparty B [Member] \| Current Assets [Member]	'	'
Summary of gross liability balances of derivative instruments	'	'
Amounts subject to master netting arrangements presented on a gross basis	138	82
Counterparty B [Member] \| Long-term liabilities [Member]	'	'
Summary of gross liability balances of derivative instruments	'	'
Gross amounts of recognized liabilities	1,039	339
Gross amounts netted in the consolidated balance sheet	-1,039	-339
Net amounts of liabilities presented in the condensed consolidated balance sheet	0	0
Counterparty C [Member] \| Current liabilities [Member]	'	'
Summary of gross liability balances of derivative instruments	'	'
Gross amounts of recognized liabilities	3,782	'
Gross amounts netted in the consolidated balance sheet	-2,289	'
Net amounts of liabilities presented in the condensed consolidated balance sheet	1,493	'
Counterparty C [Member] \| Current Assets [Member]	'	'
Summary of gross liability balances of derivative instruments	'	'
Amounts subject to master netting arrangements presented on a gross basis	301	'
Counterparty C [Member] \| Long-term liabilities [Member]	'	'
Summary of gross liability balances of derivative instruments	'	'
Gross amounts of recognized liabilities	1,122	'
Gross amounts netted in the consolidated balance sheet	-1,122	'
Net amounts of liabilities presented in the condensed consolidated balance sheet	$0	'

Derivative_Financial_Instrumen6

Derivative Financial Instruments (Details 4) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Summary of location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations	'	'	'	'
Realized (loss) gain on derivatives	($1,165)	$3,371	($519)	$11,147
Unrealized gain (loss) on derivatives	-9,327	-12,993	-6,626	-1,149
Total	-10,492	-9,622	-7,145	9,998
Revenues [Member]	'	'	'	'
Summary of location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations	'	'	'	'
Realized (loss) gain on derivatives	-1,165	3,371	-519	11,147
Unrealized gain (loss) on derivatives	-9,327	-12,993	-6,626	-1,149
Oil [Member] \| Revenues [Member]	'	'	'	'
Summary of location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations	'	'	'	'
Realized (loss) gain on derivatives	-1,519	374	-1,984	1,093
Unrealized gain (loss) on derivatives	-8,132	-9,053	-6,818	-7,364
Natural Gas [Member] \| Revenues [Member]	'	'	'	'
Summary of location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations	'	'	'	'
Realized (loss) gain on derivatives	161	2,996	790	10,053
Unrealized gain (loss) on derivatives	57	-3,985	-132	6,170
NGL's [Member] \| Revenues [Member]	'	'	'	'
Summary of location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations	'	'	'	'
Realized (loss) gain on derivatives	193	1	675	1
Unrealized gain (loss) on derivatives	($1,252)	$45	$324	$45

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Assets (Liabilities)	'	'
Certificates of deposit	$40	$230
Oil, natural gas and NGL derivatives	-2,146	'
Fair value on a recurring basis [Member]	'	'
Assets (Liabilities)	'	'
Certificates of deposit	40	230
Total	-2,106	4,709
Fair value on a recurring basis [Member] \| Natural Gas [Member]	'	'
Assets (Liabilities)	'	'
Oil, natural gas and NGL derivatives	2,032	5,149
Fair value on a recurring basis [Member] \| Oil [Member]	'	'
Assets (Liabilities)	'	'
Oil, natural gas and NGL derivatives	-4,178	-670
Fair value on a recurring basis [Member] \| Level 1 [Member]	'	'
Assets (Liabilities)	'	'
Certificates of deposit	0	0
Total	'	'
Fair value on a recurring basis [Member] \| Level 1 [Member] \| Natural Gas [Member]	'	'
Assets (Liabilities)	'	'
Oil, natural gas and NGL derivatives	0	0
Fair value on a recurring basis [Member] \| Level 1 [Member] \| Oil [Member]	'	'
Assets (Liabilities)	'	'
Oil, natural gas and NGL derivatives	0	0
Fair value on a recurring basis [Member] \| Level 2 [Member]	'	'
Assets (Liabilities)	'	'
Certificates of deposit	40	230
Total	-2,106	4,709
Fair value on a recurring basis [Member] \| Level 2 [Member] \| Natural Gas [Member]	'	'
Assets (Liabilities)	'	'
Oil, natural gas and NGL derivatives	2,032	5,149
Fair value on a recurring basis [Member] \| Level 2 [Member] \| Oil [Member]	'	'
Assets (Liabilities)	'	'
Oil, natural gas and NGL derivatives	-4,178	-670
Fair value on a recurring basis [Member] \| Level 3 [Member]	'	'
Assets (Liabilities)	'	'
Certificates of deposit	0	0
Total	'	'
Fair value on a recurring basis [Member] \| Level 3 [Member] \| Natural Gas [Member]	'	'
Assets (Liabilities)	'	'
Oil, natural gas and NGL derivatives	0	0
Fair value on a recurring basis [Member] \| Level 3 [Member] \| Oil [Member]	'	'
Assets (Liabilities)	'	'
Oil, natural gas and NGL derivatives	$0	$0

Fair_Value_Measurements_Detail1

Fair Value Measurements (Details 1) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Assets (Liabilities)	'	'
Lease and well equipment inventory	$687	$877
Fair value on a non-recurring basis [Member]	'	'
Assets (Liabilities)	'	'
Lease and well equipment inventory	'	34
Total	-951	-1,209
Fair value on a non-recurring basis [Member] \| Asset retirement obligations [Member]	'	'
Assets (Liabilities)	'	'
Asset retirement obligations	-951	-1,243
Fair value on a non-recurring basis [Member] \| Level 1 [Member]	'	'
Assets (Liabilities)	'	'
Lease and well equipment inventory	'	0
Total	'	'
Fair value on a non-recurring basis [Member] \| Level 1 [Member] \| Asset retirement obligations [Member]	'	'
Assets (Liabilities)	'	'
Asset retirement obligations	0	0
Fair value on a non-recurring basis [Member] \| Level 2 [Member]	'	'
Assets (Liabilities)	'	'
Lease and well equipment inventory	'	0
Total	'	'
Fair value on a non-recurring basis [Member] \| Level 2 [Member] \| Asset retirement obligations [Member]	'	'
Assets (Liabilities)	'	'
Asset retirement obligations	0	0
Fair value on a non-recurring basis [Member] \| Level 3 [Member]	'	'
Assets (Liabilities)	'	'
Lease and well equipment inventory	'	34
Total	-951	-1,209
Fair value on a non-recurring basis [Member] \| Level 3 [Member] \| Asset retirement obligations [Member]	'	'
Assets (Liabilities)	'	'
Asset retirement obligations	($951)	($1,243)

Fair_Value_Measurements_Detail2

Fair Value Measurements (Details Textual) (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
Fair Value Measurements (Details Textual) (USD $)	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Fair Value Measurements (Textual) [Abstract]	'	'	'	'	'
Net loss on asset sales and inventory impairment	$0	$0	($192,000)	($60,000)	'
Fair Value Measurements (Additional Textual) [Abstract]	'	'	'	'	'
Additions to asset retirement obligations	'	'	1,000,000	'	1,200,000
Drilling rig [Member]	'	'	'	'	'
Fair Value Measurements (Textual) [Abstract]	'	'	'	'	'
Impairment charge for equipments held in inventory	425,000	'	'	'	'
Pipe and other equipment [Member]	'	'	'	'	'
Fair Value Measurements (Textual) [Abstract]	'	'	'	'	'
Impairment charge for equipments held in inventory	$60,464	'	'	'	'

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	3 Months Ended	9 Months Ended			3 Months Ended	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	Aug. 01, 2012	15-May-08	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2012
	acre	acre	acre		Lease agreements [Member]	Lease agreements [Member]	Lease agreements [Member]
							Area of Land [Member]
							Maximum [Member]
							sqft
Commitments and Contingencies (Textual) [Abstract]	'	'	'	'	'	'	'
Office space of headquarters	'	'	'	'	'	'	40,071
Lease period	'	30-Jun-22	'	'	'	'	'
Maximum termination outstanding obligations of contracts	$7.70	$7.70	'	'	'	'	'
Transportation and processing fee under the agreement	'	'	'	'	2	3.8	'
Commitments and Contingencies (Additional Textual) [Abstract]	'	'	'	'	'	'	'
Natural gas processing and transportation agreement	'	'5 years	'	'	'	'	'
Minimum delivery commitment to avoid paying gas deficiency fee	'	80.00%	'	'	'	'	'
Percentage of minimum delivery commitment to anticipated production	'	80.00%	'	'	'	'	'
Undiscounted minimum commitments	12.2	12.2	'	'	'	'	'
Minimum outstanding commitments	16.7	16.7	'	'	'	'	'
Issue on the deep rights below the Cotton Valley formation	1,805	1,805	'	'	'	'	'
Right to participate in working capital	25.00%	25.00%	'	'	'	'	'
Company's total revenue and overriding royalty interests on the acreage range Minimum	2.00%	2.00%	'	'	'	'	'
Company's total revenue and overriding royalty interests on the acreage range Maximum	23.00%	23.00%	'	'	'	'	'
Loss contingency, lawsuit filing date	'	'MayB 15, 2008	'	'	'	'	'
Royalty owner undivided interest in mineral	'	'	'	0.167	'	'	'
Acres reformed by court	'	'	169	'	'	'	'
Rights on remaining acres	'	'	1,636	'	'	'	'
Consent to the proposed assignment	50.00%	'	'	'	'	'	'
Percentage of costs assumed	100.00%	'	'	'	'	'	'
The amount recovered from company	100.00%	'	'	'	'	'	'
Remittance submitted to company	$8.70	$8.70	'	'	'	'	'
Lease expiring period	30-Jun-22	'	'	'	'	'	'

Supplemental_Disclosures_Detai

Supplemental Disclosures (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Summary of current accrued liabilities	'	'
Other	$3,059	$2,410
Total accrued liabilities	50,048	59,179
Accrued evaluated and unproved and unevaluated property costs [Member]	'	'
Summary of current accrued liabilities	'	'
Total accrued liabilities	38,879	45,592
Accrued support equipment and facilities costs [Member]	'	'
Summary of current accrued liabilities	'	'
Total accrued liabilities	228	1,382
Accrued stock-based compensation [Member]	'	'
Summary of current accrued liabilities	'	'
Total accrued liabilities	0	65
Accrued lease operating expenses [Member]	'	'
Summary of current accrued liabilities	'	'
Total accrued liabilities	5,656	5,218
Accrued interest on borrowings under Credit Agreement [Member]	'	'
Summary of current accrued liabilities	'	'
Total accrued liabilities	117	255
Accrued asset retirement obligations [Member]	'	'
Summary of current accrued liabilities	'	'
Total accrued liabilities	763	660
Accrued partners share of joint interest charges [Member]	'	'
Summary of current accrued liabilities	'	'
Total accrued liabilities	$890	$3,597

Supplemental_Disclosures_Detai1

Supplemental Disclosures (Details 1) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Supplemental disclosures of cash flow information	'	'
Cash paid for interest expense, net of amounts capitalized	$2,110	$442
Asset retirement obligations related to mineral properties	889	405
Asset retirement obligations related to support equipment and facilities	4	54
(Decrease) increase in liabilities for oil and natural gas properties capital expenditures	-6,288	19,067
(Decrease) increase in liabilities for support equipment and facilities	-1,100	482
(Decrease) increase in liabilities for accrued cost to issue equity	456	-332
Issuance of restricted stock units for Board and advisor services	186	34
Issuance of common stock for advisor services	25	71
Stock based compensation expense recognized as liability	715	-930
Transfer of inventory to oil and natural gas properties	$201	($91)

Subsidiary_Guarantors_Details

Subsidiary Guarantors (Details)	Sep. 30, 2013
Subsidiary Guarantors (Textual) [Abstract]	'
Ownership on subsidiaries	100.00%

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	2 Months Ended
In Millions, unless otherwise specified	Nov. 30, 2013	Aug. 06, 2013	Nov. 30, 2013
	Subsequent Event [Member]	Permian Basin [Member]	Haynesville Shale [Member]
		acre	Subsequent Event [Member]
			acre
Subsequent Event [Line Items]	'	'	'
Number of acres acquired, gross	'	9,100	900
Number of acres acquired, net	'	4,800	900
Payments to Acquire Land	$9.70	'	'

Public_Equity_Offering_Details

Public Equity Offering (Details) (USD $)	3 Months Ended	9 Months Ended
Public Equity Offering (Details) (USD $)	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 10, 2013
Public Equity Offering [Abstract]	'	'	'	'
Stock Issued During Period, Shares, Issued for Cash	9,775,000	'	'	'
Issuance Of Common Stock Under Public Offering To Underwriters By Company	'	'	'	1,275,000
Payments of Stock Issuance Costs	$7,400,000	'	'	'
Proceeds from Issuance of Common Stock	141,700,000	149,069,000	146,510,000	'
Repayments of Long-term Debt	130,000,000	'	'	'
Proceeds From Public Offering Used to Fund Working Capital	$11,700,000	'	'	'