Clayton Williams Energy (CWEI) 10-Q 4 May 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015	Apr. 30, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	CLAYTON WILLIAMS ENERGY INC /DE
Entity Central Index Key	880115
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Amendment Flag	FALSE
Entity Current Reporting Status	Yes
Entity Common Stock, Shares Outstanding		12,169,536

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
CURRENT ASSETS
Cash and cash equivalents	$7,531	$28,016
Accounts receivable:
Oil and gas sales	23,565	36,526
Joint interest and other, net of allowance for doubtful accounts of $1,204 at March 31, 2015 and December 31, 2014	4,995	14,550
Affiliates	283	322
Inventory	41,714	42,087
Deferred income taxes	7,371	6,911
Fair value of derivatives	4,632	0
Prepaids and other	2,277	4,208
TOTAL CURRENT ASSETS	92,368	132,620
PROPERTY AND EQUIPMENT
Oil and gas properties, successful efforts method	2,737,209	2,684,913
Pipelines and other midstream facilities	59,652	59,542
Contract drilling equipment	123,310	122,751
Other	20,694	20,915
PROPERTY AND EQUIPMENT, GROSS	2,940,865	2,888,121
Less accumulated depreciation, depletion and amortization	-1,584,474	-1,539,237
Property and equipment, net	1,356,391	1,348,884
OTHER ASSETS
Debt issue costs, net	12,006	12,712
Investments and other	16,169	16,669
TOTAL OTHER ASSETS	28,175	29,381
TOTAL ASSETS	1,476,934	1,510,885
Accounts payable:
Trade	43,993	93,650
Oil and gas sales	32,864	41,328
Affiliates	264	717
Accrued liabilities and other	30,568	20,658
TOTAL CURRENT LIABILITIES	107,689	156,353
NON-CURRENT LIABILITIES
Long-term debt	746,712	704,696
Deferred income taxes	155,157	164,599
Asset retirement obligations	46,231	45,697
Deferred revenue from volumetric production payment	21,609	23,129
Accrued compensation under non-equity award plans	19,369	17,866
Other	605	751
TOTAL NON-CURRENT LIABILITIES	989,683	956,738
COMMITMENTS AND CONTINGENCIES
STOCKHOLDERS' EQUITY
Preferred stock, par value $.10 per share, authorized — 3,000,000 shares; none issued	0	0
Common stock, par value $.10 per share, authorized — 30,000,000 shares: issued and outstanding — 12,169,536 shares at March 31, 2015 and December 31, 2014	1,216	1,216
Additional paid-in capital	152,686	152,686
Retained earnings	225,660	243,892
TOTAL STOCKHOLDERS' EQUITY	379,562	397,794
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$1,476,934	$1,510,885

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, except Share data, unless otherwise specified
Statement of Financial Position [Abstract]
Allowance for doubtful accounts (in dollars)	$1,204	$1,204
Preferred stock, par value (in dollars per share)	$0.10	$0.10
Preferred stock, authorized shares	3,000,000	3,000,000
Preferred stock, issued shares	0	0
Common stock, par value (in dollars per share)	$0.10	$0.10
Common stock, authorized shares	30,000,000	30,000,000
Common stock, issued shares	12,169,536	12,169,536
Common stock, outstanding shares	12,169,536	12,169,536

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
REVENUES
Oil and gas sales	$58,570	$110,586
Midstream services	1,611	1,616
Drilling rig services	23	6,879
Other operating revenues	3,938	5,524
Total revenues	64,142	124,605
COSTS AND EXPENSES
Production	23,430	26,447
Exploration:
Abandonments and impairments	1,623	3,839
Seismic and other	866	1,483
Midstream services	399	534
Drilling rig services	1,876	4,856
Depreciation, depletion and amortization	42,654	36,255
Impairment of property and equipment	2,531	3,406
Accretion of asset retirement obligations	958	886
General and administrative	9,143	11,818
Other operating expenses	844	502
Total costs and expenses	84,324	90,026
Operating income (loss)	-20,182	34,579
OTHER INCOME (EXPENSE)
Interest expense	-13,277	-12,521
Gain (loss) on derivatives	4,632	-5,041
Other	693	840
Total other income (expense)	-7,952	-16,722
Income (loss) before income taxes	-28,134	17,857
Income tax (expense) benefit	9,902	-6,465
NET INCOME (LOSS)	($18,232)	$11,392
Net income (loss) per common share:
Basic (in dollars per share)	($1.50)	$0.94
Diluted (in dollars per share)	($1.50)	$0.94
Weighted average common shares outstanding:
Basic (in shares)	12,170	12,166
Diluted (in shares)	12,170	12,166

CONSOLIDATED_STATEMENT_OF_STOC

CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY (USD $)	Total	Common Stock	Additional Paid-In Capital	Retained Earnings
In Thousands, unless otherwise specified
BALANCE at Dec. 31, 2014	$397,794	$1,216	$152,686	$243,892
BALANCE (in shares) at Dec. 31, 2014		12,170
Increase (Decrease) in Stockholders' Equity
Net loss	-18,232			-18,232
BALANCE at Mar. 31, 2015	$379,562	$1,216	$152,686	$225,660
BALANCE (in shares) at Mar. 31, 2015		12,170

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	($18,232)	$11,392
Adjustments to reconcile net income (loss) to cash provided by operating activities:
Depreciation, depletion and amortization	42,654	36,255
Impairment of property and equipment	2,531	3,406
Abandonments and impairments	1,623	3,839
Gain on sales of assets and impairment of inventory, net	-3,071	-4,640
Deferred income tax expense (benefit)	-9,902	6,465
Non-cash employee compensation	1,314	3,424
(Gain) loss on derivatives	-4,632	5,041
Cash settlements of derivatives	0	-1,137
Accretion of asset retirement obligations	-958	-886
Amortization of debt issue costs and original issue discount	747	704
Amortization of deferred revenue from volumetric production payment	1,778	2,010
Changes in operating working capital:
Accounts receivable	22,555	-4,074
Accounts payable	-26,178	5,051
Other	10,997	14,701
Net cash provided by operating activities	19,586	79,303
CASH FLOWS FROM INVESTING ACTIVITIES
Additions to property and equipment	-89,537	-99,419
Proceeds from volumetric production payment	258	296
Proceeds from sales of assets	4,995	68,979
Decrease in equipment inventory	1,707	3,389
Other	506	42
Net cash used in investing activities	-82,071	-26,713
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from long-term debt	42,000	0
Repayments of long-term debt	0	-40,000
Net cash provided by (used in) financing activities	42,000	-40,000
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	-20,485	12,590
CASH AND CASH EQUIVALENTS
Beginning of period	28,016	26,623
End of period	7,531	39,213
SUPPLEMENTAL DISCLOSURES
Cash paid for interest, net of amounts capitalized	888	176
Cash paid for income taxes	$0	$400

Nature_of_Operations

Nature of Operations	3 Months Ended
	Mar. 31, 2015
Nature of Operations Disclosures [Abstract]
Nature of Operations	Nature of Operations
	Clayton Williams Energy, Inc., a Delaware corporation,  is an independent oil and gas company engaged in the exploration for and development and production of oil and natural gas primarily in its core areas in Texas, Louisiana and New Mexico.  Unless the context otherwise requires, references to “CWEI” mean Clayton Williams Energy, Inc., the parent company, and references to the “Company,” “we,” “us” or “our” mean Clayton Williams Energy, Inc. and its consolidated subsidiaries.  Approximately 26% of CWEI’s outstanding Common Stock is beneficially owned by Clayton W. Williams, Jr. (“Mr. Williams”), Chairman of the Board and Chief Executive Officer of the Company, and approximately 25% is owned by a partnership in which Mr. Williams’ adult children are limited partners.
	Substantially all of our oil and gas production is sold under short-term contracts, which are market-sensitive.  Accordingly, our results of operations and capital resources are highly dependent upon prevailing market prices of, and demand for, oil and natural gas.  These commodity prices are subject to wide fluctuations and market uncertainties due to a variety of factors that are beyond our control.  These factors include the level of global supply and demand for oil and natural gas, market uncertainties, weather conditions, domestic governmental regulations and taxes, political and economic conditions in oil producing countries, price and availability of alternative fuels, and overall domestic and foreign economic conditions.

Presentation

Presentation	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Presentation	Presentation
	The preparation of these consolidated financial statements in conformity with accounting principles generally accepted in the United States (“GAAP”) requires our management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods.  Actual results could differ materially from those estimates.
	The consolidated financial statements include the accounts of CWEI and its wholly-owned subsidiaries.  We account for our undivided interest in oil and gas limited partnerships using the proportionate consolidation method.  Under this method, we consolidate our proportionate share of assets, liabilities, revenues and expenses of such limited partnerships.  Less than 5% of our consolidated total assets and total revenues are derived from oil and gas limited partnerships.  Substantially all intercompany transactions and balances associated with the consolidated operations have been eliminated.
	In the opinion of management, our unaudited consolidated financial statements as of March 31, 2015 and for the three months ended March 31, 2015 and 2014 include all adjustments, which are of a normal and recurring nature, that are necessary for a fair presentation in accordance with GAAP.  These interim results are not necessarily indicative of the results to be expected for the year ending December 31, 2015.
	Certain information and footnote disclosures normally included in the consolidated financial statements prepared in accordance with GAAP have been condensed or omitted in this Form 10-Q pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”).  These consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Form 10-K for the year ended December 31, 2014.
	Recent Accounting Pronouncements
	In April 2015, the FASB issued ASU No. 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs,” that requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this Update. An entity is required to apply ASU 2015-03 for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. An entity should apply ASU 2015-03 on a retrospective basis, wherein the balance sheet of each individual period presented should be adjusted to reflect the period-specific effects of applying the new guidance. Upon transition, an entity is required to comply with the applicable disclosures for a change in an accounting principle. These disclosures include the nature of and reason for the change in accounting principle, the transition method, a description of the prior-period information that has been retrospectively adjusted, and the effect of the change on the financial statement line items (that is, debt issuance cost asset and the debt liability). We are evaluating the impact that this new guidance will have on our consolidated financial statements.
	In May 2014, the Financial Accounting Standards Board (the “FASB”) issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” that outlines a new, single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance, including industry-specific guidance. This new revenue recognition model provides a five-step analysis in determining when and how revenue is recognized. The new model will require revenue recognition to depict the transfer of promised goods or services to customers in an amount that reflects the consideration a company expects to receive in exchange for those goods or services. An entity is required to apply ASU 2014-09 for annual reporting periods beginning after December 15, 2016, and interim periods within those annual periods. An entity can apply ASU 2014-09 using either a full retrospective method, meaning the standard is applied to all of the periods presented, or a modified retrospective method, meaning the cumulative effect of initially applying the standard is recognized in the most current period presented in the financial statements. We are evaluating the impact that this new guidance will have on our consolidated financial statements.

LongTerm_Debt

Long-Term Debt	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt
	Long-term debt consists of the following:
		March 31,		December 31,
		2015		2014
		(In thousands)
	7.75% Senior Notes due 2019, net of unamortized original issue discount of $288 at March 31, 2015 and $304 at December 31, 2014	$	599,712	$	599,696
	Revolving credit facility, due April 2019(a)	147,000		105,000
		$	746,712	$	704,696
	_______
	(a)	Renewed and extended in April 2014.
	Senior Notes
	In March 2011, we issued $300 million of aggregate principal amount of 7.75% Senior Notes due 2019 (the “2019 Senior Notes”).  The 2019 Senior Notes were issued at par and bear interest at 7.75% per year, payable semi-annually on April 1 and October 1 of each year.  In April 2011, we issued an additional $50 million aggregate principal amount of the 2019 Senior Notes with an original issue discount of 1% or $0.5 million.  In October 2013, we issued an additional $250 million of aggregate principal amount of the 2019 Senior Notes at par to yield 7.75% to maturity. All of the the 2019 Senior Notes are treated as a single class of debt securities under the same indenture. We may redeem some or all of the 2019 Senior Notes at redemption prices (expressed as percentages of principal amount) equal to 101.938% beginning on April 1, 2016 and 100% beginning on April 1, 2017 or for any period thereafter, in each case plus accrued and unpaid interest.
	The Indenture contains covenants that restrict our ability to:  (1) borrow money; (2) issue redeemable or preferred stock; (3) pay distributions or dividends; (4) make investments; (5) create liens without securing the 2019 Senior Notes; (6) enter into agreements that restrict dividends from subsidiaries; (7) sell certain assets or merge with or into other companies; (8) enter into transactions with affiliates; (9) guarantee indebtedness; and (10) enter into new lines of business.  One such covenant provides that we may only incur indebtedness if the ratio of consolidated EBITDAX to consolidated interest expense (as these terms are defined in the Indenture) exceeds 2.25 times.  These covenants are subject to a number of important exceptions and qualifications as described in the Indenture.  We were in compliance with these covenants at March 31, 2015 and December 31, 2014.
	Revolving Credit Facility
	We borrow money under an amended and restated credit facility with a syndicate of 16 banks led by JPMorgan Chase Bank, N.A. The credit facility provides for a revolving line of credit of up to $1 billion, limited to the lesser of the borrowing base amount, as determined by the banks, and the aggregate lender commitments, as determined by us.  The credit facility matures in April 2019 and is subject to an accelerated maturity date of October 1, 2018 unless our existing 2019 Senior Notes are refinanced or extended in accordance with the terms of the credit facility prior to October 1, 2018.
	The borrowing base, which is based on the discounted present value of future net cash flows from oil and gas production, is redetermined by the banks semi-annually in May and November.  We or the banks may also request an unscheduled borrowing base redetermination at other times during the year.  If, at any time, the borrowing base is less than the amount of outstanding credit exposure under the credit facility, we will be required to (1) provide additional security, (2) prepay the principal amount of the loans in an amount sufficient to eliminate the deficiency, (3) prepay the deficiency in not more than five equal monthly installments plus accrued interest, or (4) take any combination of options (1) through (3). Increases in aggregate lender commitments require the consent of each lender.
	The borrowing base under the credit facility was $600 million at December 31, 2014 and was decreased in February 2015 to $500 million. The aggregate lender commitment remained at $500 million. At March 31, 2015, we had $147 million of borrowings outstanding on the credit facility, leaving $347.1 million available after allowing for outstanding letters of credit totaling $5.9 million.
	The credit facility is collateralized primarily by 80% or more of the adjusted engineered value (as defined in the credit facility) of our oil and gas interests evaluated in determining the borrowing base.  The obligations under the credit facility are guaranteed by each of CWEI’s material domestic subsidiaries except for CWEI Andrews Properties, GP, LLC (see Note 17).
	At our election, annual interest rates under the credit facility are determined by reference to (1) LIBOR plus an applicable LIBOR margin or (2) if an alternate base rate loan, the greatest of (A) the prime rate, (B) the federal funds rate plus 0.50%, or (C) one-month LIBOR plus 1%, plus an applicable base rate margin. The LIBOR margin ranges between 1.75% and 2.75% per year (as amended in February 2015), and the base rate margin ranges between 0.75% and 1.75% per year (as amended in February 2015).  We also pay a commitment fee on the unused portion of the credit facility at an applicable margin that ranges between 0.375% and 0.50% per year.  Applicable margins are based on actual borrowings outstanding as a percentage of the borrowing base.  Interest and fees are payable no less often than quarterly.  The effective annual interest rate on borrowings under the credit facility, excluding bank fees and amortization of debt issue costs, for the three months ended March 31, 2015 was 2%.
	The credit facility also contains various covenants and restrictive provisions that may, among other things, limit our ability to sell assets, incur additional indebtedness, make investments or loans and create liens.  One such covenant requires that we maintain a ratio of consolidated current assets to consolidated current liabilities of at least 1 to 1.  Another financial covenant is a leverage ratio that limits our consolidated indebtedness to consolidated EBITDAX (determined as of the end of each fiscal quarter for the then most-recently ended four fiscal quarters) from being greater than 4 to 1.  In February 2015, the credit facility was amended to temporarily redefine the leverage ratio to limit consolidated senior debt to 2.5 times consolidated EBITDAX and to add a consolidated interest coverage ratio of 1.5 times consolidated EBITDAX. These temporary amendments apply to each of the quarterly periods from January 1, 2015 through June 30, 2016. The computations of consolidated current assets, current liabilities, EBITDAX, indebtedness and interest are defined in the credit facility.  We were in compliance with all financial and non-financial covenants at March 31, 2015 and December 31, 2014.

Sales_of_Assets

Sales of Assets	3 Months Ended
	Mar. 31, 2015
Sale Of Assets [Abstract]
Sale of Assets	Sales of Assets
	In March 2015, we closed a transaction to assign our interests in selected wells in Martin County, Texas for $2.9 million and we sold our interests in selected wells in Yoakum County, Texas for $0.8 million, subject to customary closing adjustments.
	In March 2014, we closed a transaction to sell our interests in selected wells and leases in Wilson, Brazos, La Salle, Frio and Robertson Counties, Texas for $71 million, subject to customary closing adjustments. At closing, $6.8 million of the total proceeds was placed in escrow pending resolution of certain title requirements, $4.3 million of which was released in June 2014 and $131,000 was released in March 2015. As of April 2015, the remaining title requirements have been satisfied and we expect the $2.4 million of retained proceeds to be released in 2015. In February 2014, we sold a property in Ward County, Texas for $5.1 million, subject to customary closing adjustments.
	Net proceeds from each of these transactions were applied to repay a portion of the outstanding balance on the credit facility at the time of receipt.

Asset_Retirement_Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations
	We record asset retirement obligations (“ARO”) associated with the retirement of our long-lived assets in the period in which they are incurred and become determinable. Under this method, we record a liability for the expected future cash outflows discounted at our credit-adjusted risk-free interest rate for the dismantlement and abandonment costs, excluding salvage values, of each oil and gas property. We also record an asset retirement cost to the oil and gas properties equal to the ARO liability. The fair value of the asset retirement cost and the ARO liability is measured using primarily Level 3 inputs. The significant unobservable inputs to this fair value measurement include estimates of plugging, abandonment and remediation costs, inflation rate and well life.  The inputs are calculated based on historical data as well as current estimated costs. Accretion of the liability is recognized each period using the interest method of allocation, and the capitalized cost is depleted over the useful life of the related asset.
	The following table reflects the changes in ARO during the three months ended March 31, 2015 and the year ended December 31, 2014:
		March 31,			December 31,
		2015			2014
		(In thousands)
	Beginning of period	$	45,697		$	49,981
	Additional ARO from new properties	248			1,209
	Sales or abandonments of properties	(484		)	(5,246		)
	Accretion expense	958			3,662
	Revisions of previous estimates	(188		)	(3,909		)
	End of period	$	46,231		$	45,697

Deferred_Revenue_from_Volumetr

Deferred Revenue from Volumetric Production Payment	3 Months Ended
	Mar. 31, 2015
Deferred Revenue Disclosure [Abstract]
Deferred Revenue from Volumetric Production Payment	Deferred Revenue from Volumetric Production Payment
	In March 2012, Southwest Royalties, Inc. (“SWR”), a wholly owned subsidiary of CWEI, completed the mergers of each of the 24 limited partnerships of which SWR was the general partner, into SWR, with SWR continuing as the surviving entity in the mergers. To obtain the funds to finance the aggregate merger consideration, SWR entered into a volumetric production payment (“VPP”) with a third party for upfront cash proceeds of $44.4 million and deferred future advances aggregating $4.7 million. Under the terms of the VPP, SWR conveyed to the third party a term overriding royalty interest covering approximately 725 MBOE of estimated future oil and gas production from certain properties derived from the mergers. The scheduled volumes under the VPP relate to production months from March 2012 through December 2019 and are to be delivered to, or sold on behalf of, the third party free of all costs associated with the production and development of the underlying properties. Once the scheduled volumes have been delivered to the third party, the term overriding royalty interest will terminate. SWR retained the obligation to prudently operate and produce the properties during the term of the VPP, and the third party assumed all risks associated with product prices. As a result, the VPP has been accounted for as a sale of reserves, with the sales proceeds being deferred and amortized into oil and gas sales as the scheduled volumes are produced. The net proceeds from the VPP are recorded as a non-current liability in the consolidated balance sheets.  Deferred revenue from the VPP will be amortized over the life of the VPP and will be recognized in oil and gas sales in the consolidated statements of operations and comprehensive income (loss). As of March 31, 2015, we have a remaining obligation to deliver approximately 349 MBOE.
	The following table reflects the changes in the deferred revenue during the three months ended March 31, 2015 and the year ended December 31, 2014:
		March 31,			December 31,
		2015			2014
		(In thousands)
	Beginning of period	$	23,129		$	29,770
	Deferred revenue from VPP	258			1,067
	Amortization of deferred revenue from VPP	(1,778		)	(7,708		)
	End of period	$	21,609		$	23,129

Compensation_Plans

Compensation Plans	3 Months Ended
	Mar. 31, 2015
Compensation Plans [Abstract]
Compensation Plans	Compensation Plans
	Non-Equity Award Plans
	The Compensation Committee of the Board has adopted an after-payout (“APO”) incentive plan (the “APO Incentive Plan”) for officers, key employees and consultants who promote our drilling and acquisition programs.  The Compensation Committee’s objective in adopting this plan is to further align the interests of the participants with ours by granting the participants an APO interest in the production developed, directly or indirectly, by the participants.  The plan generally provides for the creation of a series of partnerships or participation arrangements, which are treated as partnerships for tax purposes (“APO Partnerships”), between us and the participants, to which we contribute a portion of our economic interest in wells drilled or acquired within certain areas.  Generally, we pay all costs to acquire, drill and produce applicable wells and receive all revenues until we have recovered all of our costs, plus interest (“payout”).  At payout, the participants receive 99% to 100% of all subsequent revenues and pay 99% to 100% of all subsequent expenses attributable to the economic interests that are subject to the APO Partnerships.  Between 5% and 7.5% of our economic interests in specified wells drilled or acquired by us subsequent to October 2002 are subject to the APO Incentive Plan.  We record our allocable share of the assets, liabilities, revenues, expenses and oil and gas reserves of these APO Partnerships in our consolidated financial statements.  Participants in the APO Incentive Plan are immediately vested in all future amounts payable under the plan.
	The Compensation Committee has also adopted an APO reward plan (the “APO Reward Plan”) which offers eligible officers, key employees and consultants the opportunity to receive bonus payments that are based on certain profits derived from a portion of our working interest in specified areas where we are conducting drilling and production enhancement operations.  The wells subject to the APO Reward Plan are not included in the APO Incentive Plan.  Likewise, wells included in the APO Incentive Plan are not included in the APO Reward Plan.  Although conceptually similar to the APO Incentive Plan, the APO Reward Plan is a compensatory bonus plan through which we pay participants a bonus equal to a portion of the APO cash flows received by us from our working interest in wells in a specified area.  Unlike the APO Incentive Plan, however, participants in the APO Reward Plan are not immediately vested in all future amounts payable under the plan.  To date, we have granted awards under the APO Reward Plan in 15 specified areas, each of which established a quarterly bonus amount equal to 7% or 10% of the APO cash flow from wells drilled or recompleted in the respective areas after the effective date set forth in each plan, which dates range from January 1, 2007 to June 11, 2014.  Of these 15 awards, eight awards are fully vested, two awards fully vested on May 1, 2015, two awards will fully vest on August 1, 2015 and three awards will fully vest on June 23, 2016.
	In January 2007, we granted awards under the Southwest Royalties Reward Plan (the “SWR Reward Plan”), a one-time incentive plan which established a quarterly bonus amount for participants equal to the APO cash flow from a 22.5% working interest in one well.  The plan is fully vested and 100% of subsequent quarterly bonus amounts are payable to participants.
	To continue as a participant in the APO Reward Plan or the SWR Reward Plan, participants must remain in the employment or service of the Company through the full vesting date established for each award.  The full vesting date may be accelerated in the event of a change of control or sale transaction, as defined in the plan documents.
	We recognize compensation expense related to the APO Partnerships based on the estimated value of economic interests conveyed to the participants. Estimated compensation expense applicable to the APO Reward Plan and SWR Reward Plan is recognized over the applicable vesting periods, which range from two years to five years. Compensation expense related to non-equity award plans for the three months ended March 31, 2015 and 2014 was $2.1 million and $4.7 million, respectively.
	Accrued compensation under non-equity award plans is reflected in the accompanying consolidated balance sheets as detailed in the following schedule:
		March 31,		December 31,
		2015		2014
		(In thousands)
	Current liabilities:
	Accrued liabilities and other	$	2,128	$	2,317
	Non-current liabilities:
	Accrued compensation under non-equity award plans	19,369		17,866
	Total accrued compensation under non-equity award plans	$	21,497	$	20,183

Derivatives

Derivatives	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives
	Commodity Derivatives
	From time to time, we utilize commodity derivatives in the form of swap contracts to attempt to optimize the price received for our oil and gas production.  Under swap contracts, we receive a fixed price for the respective commodity and pay a floating market price as defined in each contract, generally New York Mercantile Exchange (“NYMEX”) futures prices, resulting in a net amount due to or from the counterparty.  Commodity derivatives are settled monthly as the contract production periods mature.
	The following summarizes information concerning our net positions in open commodity derivatives applicable to periods subsequent to March 31, 2015.  The settlement prices of commodity derivatives are based on NYMEX futures prices.
	Swaps
		Oil
		MBbls			Price
	Production Period:
	2nd Quarter 2015	448			$	55.65
	3rd Quarter 2015	697			$	55.65
	4th Quarter 2015	592			$	55.65
		1,737
	We use a sensitivity analysis technique to evaluate the hypothetical effect that changes in the market value of oil and gas may have on the fair value of our commodity derivatives.  As of March 31, 2015, a $1 per barrel change in the price of oil would change the fair value of our commodity derivatives by approximately $1.7 million.
	Accounting For Derivatives
	We did not designate any of our currently open commodity derivatives as cash flow hedges; therefore, all changes in the fair value of these contracts prior to maturity, plus any realized gains or losses at maturity, are recorded as other income (expense) in our consolidated statements of operations and comprehensive income (loss).
	Effect of Derivative Instruments on the Consolidated Balance Sheets
		Fair Value of Derivative Instruments as of March 31, 2015
		Asset Derivatives						Liability Derivatives
		Balance Sheet						Balance Sheet
		Location		Fair Value				Location		Fair Value
				(In thousands)						(In thousands)
	Derivatives not designated as hedging instruments:
	Commodity derivatives	Fair value of derivatives:						Fair value of derivatives:
		Current		$	4,632			Current		$	—
		Non-current		—				Non-current		—
	Total			$	4,632					$	—
		Fair Value of Derivative Instruments as of December 31, 2014
		Asset Derivatives						Liability Derivatives
		Balance Sheet						Balance Sheet
		Location		Fair Value				Location		Fair Value
				(In thousands)						(In thousands)
	Derivatives not designated as hedging instruments:
	Commodity derivatives	Fair value of derivatives:						Fair value of derivatives:
		Current		$	—			Current		$	—
		Non-current		—				Non-current		—
	Total			$	—					$	—
	Gross to Net Presentation Reconciliation of Derivative Assets and Liabilities
		31-Mar-15
		Assets				Liabilities
		(In thousands)
	Fair value of derivatives — gross presentation	$	4,632			$	—
	Effects of netting arrangements	—				—
	Fair value of derivatives — net presentation	$	4,632			$	—
		31-Dec-14
		Assets				Liabilities
		(In thousands)
	Fair value of derivatives — gross presentation	$	—			$	—
	Effects of netting arrangements	—				—
	Fair value of derivatives — net presentation	$	—			$	—
	Our derivative contracts are with JPMorgan Chase Bank, N.A. We have elected to net the outstanding positions with this counterparty between current and noncurrent assets or liabilities since we have the right to settle these positions on a net basis.
	Effect of Derivative Instruments Recognized in Earnings on the Consolidated Statements of Operations and Comprehensive Income (Loss)
			Amount of Gain or (Loss) Recognized in Earnings
			Three Months Ended
			March 31,
	Location of Gain or (Loss) Recognized in Earnings		2015				2014
			(In thousands)
	Derivatives not designated as hedging instruments:
	Commodity derivatives:
	Other income (expense) -
	Gain (loss) on derivatives		$	4,632			$	(5,041	)
	Total		$	4,632			$	(5,041	)

Fair_Value_of_Financial_Instru

Fair Value of Financial Instruments	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	Fair Value of Financial Instruments
	Cash and cash equivalents, receivables, accounts payable and accrued liabilities were each estimated to have a fair value approximating the carrying amount due to the short maturity of those instruments.  Indebtedness under our revolving credit facility was estimated to have a fair value approximating the carrying amount since the interest rate is generally market sensitive.
	Fair Value Measurements
	We follow a framework for measuring fair value, which outlines a fair value hierarchy based on the quality of inputs used to measure fair value and enhances disclosure requirements for fair value measurements.  Fair value is defined as the price at which an asset could be exchanged in a current transaction between knowledgeable, willing parties at the measurement date. Where available, fair value is based on observable market prices or parameters or derived from such prices or parameters. Where observable prices or inputs are not available, use of unobservable prices or inputs are used to estimate the current fair value, often using an internal valuation model. These valuation techniques involve some level of management estimation and judgment, the degree of which is dependent on the item being valued.  We categorize our assets and liabilities recorded at fair value in the accompanying consolidated balance sheets based upon the level of judgment associated with the inputs used to measure their fair value.
	Hierarchical levels directly related to the amount of subjectivity associated with the inputs to fair valuation of these assets and liabilities, are as follows:
	Level 1 -	Inputs are unadjusted, quoted prices in active markets for identical assets or liabilities at the measurement date.
	Level 2 -	Inputs (other than quoted prices included in Level 1) are either directly or indirectly observable for the asset or liability through correlation with market data at the measurement date and for the duration of the instrument’s anticipated life.
	Level 3 -	Inputs reflect management’s best estimate of what market participants would use in pricing the asset or liability at the measurement date. Consideration is given to the risk inherent in the valuation technique and the risk inherent in the inputs to the model.
	The financial assets and liabilities measured on a recurring basis at March 31, 2015 and December 31, 2014 were commodity derivatives.  The fair value of all derivative contracts is reflected on the consolidated balance sheet as detailed in the following schedule:
			March 31,		December 31,
			2015		2014
			Significant Other
			Observable Inputs
	Description		(Level 2)
			(In thousands)
	Assets:
	Fair value of commodity derivatives		$	4,632	$	—
	Total assets		$	4,632	$	—
	Liabilities:
	Fair value of commodity derivatives		$	—	$	—
	Total liabilities		$	—	$	—
	Fair Value of Other Financial Instruments
	We estimate the fair value of our 2019 Senior Notes using quoted market prices (Level 1 inputs). Fair value is compared to the carrying value in the table below:
			31-Mar-15				31-Dec-14
			Carrying		Estimated		Carrying		Estimated
	Description		Amount		Fair Value		Amount		Fair Value
			(In thousands)
	7.75% Senior Notes due 2019		$	599,712	$	558,000	$	599,696	$	510,000

Income_Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes
	Our effective federal and state income tax rate for the three months ended March 31, 2015 of 35.2% differed from the statutory federal rate of 35% due primarily to increases related to the effects of the Texas Margin Tax and certain non-deductible expenses, offset in part by tax benefits derived from excess statutory depletion deductions.
	We file federal income tax returns with the United States Internal Revenue Service and state income tax returns in various state tax jurisdictions.  Our tax returns for fiscal years after 2011 currently remain subject to examination by appropriate taxing authorities.  None of our income tax returns are under examination at this time.

Other_Operating_Revenues_and_E

Other Operating Revenues and Expenses	3 Months Ended
	Mar. 31, 2015
Other Operating Revenues [Abstract]
Other Operating Revenues and Expenses	Other Operating Revenues and Expenses
	Other operating revenues and expenses for the three months ended March 31, 2015 and March 31, 2014 are as follows:
		Three Months Ended
		March 31,
		2015			2014
		(In thousands)
	Other operating revenues:
	Gain on sales of assets	$	3,915		$	5,142
	Marketing revenue	23			382
	Total other operating revenues	$	3,938		$	5,524
	Other operating expenses:
	Loss on sales of assets	$	(61	)	$	(492	)
	Impairment of inventory	(783		)	(10		)
	Total other operating expenses	$	(844	)	$	(502	)
	During the three months ended March 31, 2015, gain on sales of assets included the sale of selected wells in Martin and Yoakum Counties, Texas in March 2015 (See Note 4).
	During the three months ended March 31, 2014, gain on sales of assets included the sale of certain non-core Austin Chalk/Eagle Ford assets in March 2014 and the sale of a property in Ward County, Texas in February 2014 (see Note 4).
	We maintain an inventory of tubular goods and other well equipment for use in our exploration and development drilling activities.  Inventory is carried at the lower of average cost or estimated fair market value.  We categorize the measurement of fair value of inventory as Level 2 under applicable accounting standards.  To determine estimated fair value of inventory, we subscribe to market surveys and obtain quotes from equipment dealers for similar equipment.  We then correlate the data as needed to estimate the fair value of the specific items (or groups of similar items) in our inventory.  If the estimated fair values for those specific items (or groups of similar items) in our inventory are less than the related average cost, a provision for impairment is made.

Investment_in_Dalea_Investment

Investment in Dalea Investment Group, LLC	3 Months Ended
	Mar. 31, 2015
Investments, All Other Investments [Abstract]
Investment in Dalea Investment Group, LLC	Investment in Dalea Investment Group, LLC
	In June 2012, we cancelled an $11 million note receivable in exchange for a 7.66% non-controlling membership interest in Dalea Investment Group, LLC (“Dalea”), an international oilfield services company formed in March 2012.  Since the membership interests in Dalea are privately-held and are not traded in an active market, our investment in Dalea is carried at cost of $11 million.  As of March 31, 2015, we have performed a qualitative assessment based on the difference between the carrying value and the estimated fair value of our investment. We estimated the fair value of our investment by comparing our interest of the equity in Dalea to our carrying value at March 31, 2015 and December 31, 2014. Due to the estimated fair value being less than our carrying value at March 31, 2015, we recorded an impairment of $0.9 million on our investment in Dalea for the three months ended March 31, 2015 and none for the three months ended March 31, 2014. We categorize the measurement of fair value of this investment as a Level 3 input.

Costs_of_Oil_and_Gas_Propertie

Costs of Oil and Gas Properties	3 Months Ended
	Mar. 31, 2015
Oil and Gas Property, Successful Effort Method, Gross [Abstract]
Costs of Oil and Gas Properties	Costs of Oil and Gas Properties
	The following table sets forth the net capitalized costs for oil and gas properties as of March 31, 2015 and December 31, 2014.
		March 31,			December 31,
		2015			2014
		(In thousands)
	Proved properties	$	2,683,534		$	2,585,279
	Unproved properties	53,675			99,634
	Total capitalized costs	2,737,209			2,684,913
	Accumulated depletion	(1,472,112		)	(1,430,699		)
	Net capitalized costs	$	1,265,097		$	1,254,214

Commitments_and_Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies
	Legal Proceedings
	SWR is a defendant in a suit filed in April 2011 in the Circuit Court of Union County, Arkansas where the plaintiffs initially sought in excess of $8 million for the costs of environmental remediation to a lease on which operations were commenced in the 1930s. In June 2013, the plaintiffs, SWR and the remaining defendants agreed to a settlement of $0.8 million, of which SWR would pay $0.7 million. To accomplish the settlement, the case was converted to a class action, and each member of the class was offered the right to either participate or opt out of the class and continue a separate action for damages. One plaintiff opted out and will be subject to all previous rulings of the court, including an order dismissing certain claims on the basis that such claims were time barred. A loss on settlement of $0.7 million was recorded for the year ended December 31, 2013 in connection with this proposed settlement. The settlement was entered by the Court on December 19, 2014, and all settlement funds were paid to plaintiffs’ counsel in January 2015. The case against the single plaintiff will continue in 2015.
	In February 2012, BMT O&G TX, L.P. filed a suit in the 143rd Judicial District in Reeves County, Texas to terminate a lease under our farm-in agreement with Chesapeake Exploration, L.L.C. (“Chesapeake”). Plaintiffs are the lessors and claim a breach of the lease which they allege gives rise to termination of the lease. CWEI denies a breach and argues in the alternative that (i) any breach was cured in accordance with the lease and (ii) a breach will not give rise to lease termination. In October 2013, a judge ruled that CWEI and Chesapeake are jointly and severally liable for damages to plaintiffs in the amount of approximately $2.9 million and attorney fees of $0.8 million. A loss of $1.4 million was recorded for the year ended December  31, 2013 in connection with the judgment. CWEI is appealing the judgment. All appellate briefs have been filed with the El Paso Court of Appeals, and argument has been scheduled for June 4, 2015.
	CWEI has been named a defendant in three lawsuits filed in Louisiana, one by Southeast Louisiana Flood Protection Authority-East (“SELFPA”) and two by Plaquemines Parish, each alleging that historical industry operations have significantly damaged coastal marshlands.
	In July 2013, the SELFPA case was filed in Orleans Parish and alleged that dredging and other oilfield operations of the 95 oil and gas company defendants caused degradation and destruction of the coastal marshlands which serve as a buffer protecting the coastal area of Louisiana from storms. The case was removed to Federal District Court. Legislation was enacted in Louisiana
	in 2014 in response to the suit which would effectively eliminate the claims, but in late 2014 the Louisiana state court judge declared the new law unconstitutional. A motion to dismiss the claims was granted in Federal District Court and the plaintiff has appealed to the United States Fifth Circuit.
	In November 2013, we were served with two separate suits filed by Plaquemines Parish in the 25th Judicial District Court of Plaquemines Parish, Louisiana (Designated Case Nos. 61-002 and 60-982). Multiple defendants are named in each suit, and each suit involves a different area of operation within Plaquemines Parish. Except as to the named defendants and area of operations, the suits are identical. Plaintiff alleges that defendants’ oil and gas operations violated certain laws relating to the coastal zone management including failure to obtain permits, violation of permits, use of unlined waste pits, discharge of oil field wastes, including naturally occurring radioactive material, and that dredging operations exceeded unspecified permit limitations. Plaintiff makes no specific allegations against any individual defendant and seeks unspecified monetary damages and declaratory relief, as well as restoration, costs of remediation and attorney fees. The cases were removed to the U.S. District Court for the Eastern District of Louisiana and have since been remanded in 2015 back to the state court.
	Our overall exposure to these three suits is not currently determinable and we intend to vigorously defend these cases. We are also a defendant in several other lawsuits that have arisen in the ordinary course of business. While the outcome of these lawsuits cannot be predicted with certainty, management does not expect any of these to have a material adverse effect on our consolidated financial condition or results of operations.

Impairment_of_Property_and_Equ

Impairment of Property and Equipment	3 Months Ended
	Mar. 31, 2015
Property, Plant and Equipment Impairment or Disposal [Abstract]
Impairment of Property and Equipment	Impairment of Property and Equipment
	We impair our long-lived assets, including oil and gas properties and contract drilling equipment, when estimated undiscounted future net cash flows of an asset are less than its carrying value.  The amount of any such impairment is recognized based on the difference between the carrying value and the estimated fair value of the asset.  We categorize the measurement of fair value of these assets as Level 3 inputs.  We estimate the fair value of the impaired property by applying weighting factors to fair values determined under three different methods: (1) discounted cash flow method; (2) flowing daily production method; and (3) proved reserves per BOE method. We then assign applicable weighting factors based on the relevant facts and circumstances.  We utilize all three methods when that information is available, or if not will utilize the discounted cash flow method. We recorded provisions for impairment of proved properties of $2.5 million for the three months ended March 31, 2015 and $3.4 million for the three months ended March 31, 2014.  The provision for the three months ended March 31, 2015 of $2.5 million related to the write-down of certain non-core properties located in Louisiana to their estimated fair value. The provision for the three months ended March 31, 2014 of $3.4 million related to the write-down of certain non-operated properties located in North Dakota to their estimated fair value.
	Unproved properties are nonproducing and do not have estimable cash flow streams. Therefore, we estimate the fair value of individually significant prospects by obtaining, when available, information about recent market transactions in the vicinity of the prospects and adjust the market data as needed to give consideration to the proximity of the prospects to known fields and reservoirs, the extent of geological and geophysical data on the prospects, the remaining terms of leases holding the acreage in the prospects, recent drilling results in the vicinity of the prospects, and other risk-related factors such as drilling and completion costs, estimated product prices and other economic factors. Individually insignificant prospects are grouped and impaired based on remaining lease terms and our historical experience with similar prospects. Based on the assessments previously discussed, we will impair our unproved oil and gas properties when we determine that a prospect’s carrying value exceeds its estimated fair value. We categorize the measurement of fair value of unproved properties as Level 3 inputs. We recorded provisions for impairment of unproved properties aggregating $0.2 million for the three months ended March 31, 2015 and $3.5 million for the three months ended March 31, 2014, and charged these impairments to abandonments and impairments in the accompanying consolidated statements of operations and comprehensive income (loss).

Segment_Information

Segment Information	3 Months Ended
	Mar. 31, 2015
Segment Reporting [Abstract]
Segment Information	Segment Information
	We have two reportable operating segments, which are (1) oil and gas exploration and production and (2) contract drilling services. The following tables present selected financial information regarding our operating segments for the three months ended March 31, 2015 and 2014:
	For the Three Months Ended
	31-Mar-15
	(Unaudited)					Contract			Intercompany			Consolidated
	(In thousands)		Oil and Gas			Drilling			Eliminations			Total
	Revenues		$	64,080		$	680		$	(618	)	$	64,142
	Depreciation, depletion and amortization (a)		42,076			3,204			(95		)	45,185
	Other operating expenses (b)		37,201			2,788			(850		)	39,139
	Interest expense		13,277			—			—			13,277
	Other (income) expense		(5,325		)	—			—			(5,325		)
	Income (loss) before income taxes		(23,149		)	(5,312		)	327			(28,134		)
	Income tax (expense) benefit		8,043			1,859			—			9,902
	Net income (loss)		$	(15,106	)	$	(3,453	)	$	327		$	(18,232	)
	Total assets		$	1,458,121		$	61,272		$	(42,459	)	$	1,476,934
	Additions to property and equipment		$	54,510		$	636		$	328		$	55,474
	For the Three Months Ended
	31-Mar-14
	(Unaudited)					Contract			Intercompany			Consolidated
	(In thousands)		Oil and Gas			Drilling			Eliminations			Total
	Revenues		$	117,720		$	13,420		$	(6,535	)	$	124,605
	Depreciation, depletion and amortization (a)		37,382			3,168			(889		)	39,661
	Other operating expenses (b)		45,447			9,914			(4,996		)	50,365
	Interest expense		12,521			—			—			12,521
	Other (income) expense		4,201			—			—			4,201
	Income (loss) before income taxes		18,169			338			(650		)	17,857
	Income tax (expense) benefit		(6,347		)	(118		)	—			(6,465		)
	Net income (loss)		$	11,822		$	220		$	(650	)	$	11,392
	Total assets		$	1,332,223		$	58,245		$	(27,638	)	$	1,362,830
	Additions to property and equipment		$	85,193		$	7,657		$	(651	)	$	92,199
	_______
	(a)	Includes impairment of property and equipment.
	(b)	Includes the following expenses: production, exploration, midstream services, drilling rig services, accretion of ARO, G&A and other operating expenses.

Guarantor_Financial_Informatio

Guarantor Financial Information	3 Months Ended
	Mar. 31, 2015
Guarantor Financial Information Disclosure [Abstract]
Guarantor Financial Information	Guarantor Financial Information
	In March and April 2011, we issued $350 million of aggregate principal amount of 2019 Senior Notes. In October 2013, we issued an additional $250 million of aggregate principal amount of the 2019 Senior Notes. The 2019 Senior Notes issued in October 2013 and the 2019 Senior Notes originally issued in March and April 2011 are treated as a single class of debt securities under the same indenture (see Note 3). Presented below is condensed consolidated financial information of CWEI (the “Issuer”) and the Issuer’s material wholly owned subsidiaries. Other than CWEI Andrews Properties, GP, LLC, the general partner of CWEI Andrews Properties, L.P., an affiliated limited partnership formed in April 2013, all of the Issuer’s wholly owned and active subsidiaries (“Guarantor Subsidiaries”) have jointly and severally, irrevocably and unconditionally guaranteed the performance and payment when due of all obligations under the 2019 Senior Notes. The guarantee by a Guarantor Subsidiary of the 2019 Senior Notes may be released under certain customary circumstances as set forth in the Indenture. CWEI Andrews Properties, GP, LLC, is not a guarantor of the 2019 Senior Notes and its accounts are reflected in the “Non-Guarantor Subsidiary” column in this Note 17.
	The financial information which follows sets forth our condensed consolidating financial statements as of and for the periods indicated.
	Condensed Consolidating Balance Sheet
	31-Mar-15
	(Unaudited)
	(Dollars in thousands)
		Issuer			Guarantor			Non-Guarantor			Adjustments/			Consolidated
					Subsidiaries			Subsidiary			Eliminations
	Current assets	$	115,996		$	297,375		$	1,034		$	(322,037	)	$	92,368
	Property and equipment, net	1,001,308			336,654			18,429			—			1,356,391
	Investments in subsidiaries	356,523			—			—			(356,523		)	—
	Other assets	14,859			13,316			—			—			28,175
	Total assets	$	1,488,686		$	647,345		$	19,463		$	(678,560	)	$	1,476,934
	Current liabilities	$	314,241		$	115,722		$	220		$	(322,494	)	$	107,689
	Non-current liabilities:
	Long-term debt	746,712			—			—			—			746,712
	Deferred income taxes	115,507			140,546			4,465			(105,361		)	155,157
	Other	38,482			49,148			184			—			87,814
		900,701			189,694			4,649			(105,361		)	989,683
	Equity	273,744			341,929			14,594			(250,705		)	379,562
	Total liabilities and equity	$	1,488,686		$	647,345		$	19,463		$	(678,560	)	$	1,476,934
	Condensed Consolidating Balance Sheet
	December 31, 2014
	(Dollars in thousands)
		Issuer			Guarantor			Non-Guarantor			Adjustments/			Consolidated
					Subsidiaries			Subsidiary			Eliminations
	Current assets	$	153,373		$	293,613		$	546		$	(314,912	)	$	132,620
	Property and equipment, net	986,110			344,174			18,600			—			1,348,884
	Investments in subsidiaries	359,777			—			—			(359,777		)	—
	Other assets	16,077			13,304			—			—			29,381
	Total assets	$	1,515,337		$	651,091		$	19,146		$	(674,689	)	$	1,510,885
	Current liabilities	$	352,889		$	113,746		$	586		$	(310,868	)	$	156,353
	Non-current liabilities:
	Long-term debt	704,696			—			—			—			704,696
	Deferred income taxes	129,105			141,130			4,227			(109,863		)	164,599
	Other	36,671			50,591			181			—			87,443
		870,472			191,721			4,408			(109,863		)	956,738
	Equity	291,976			345,624			14,152			(253,958		)	397,794
	Total liabilities and equity	$	1,515,337		$	651,091		$	19,146		$	(674,689	)	$	1,510,885
	Condensed Consolidating Statement of Operations and Comprehensive Income (Loss)
	Three Months Ended March 31, 2015
	(Unaudited)
	(Dollars in thousands)
		Issuer			Guarantor			Non-Guarantor			Adjustments/			Consolidated
					Subsidiaries			Subsidiary			Eliminations
	Total revenue	$	45,688		$	18,042		$	412		$	—		$	64,142
	Costs and expenses	61,021			22,675			628			—			84,324
	Operating income (loss)	(15,333		)	(4,633		)	(216		)	—			(20,182		)
	Other income (expense)	(9,027		)	179			896			—			(7,952		)
	Equity in earnings of subsidiaries	(2,453		)	—			—			2,453			—
	Income tax (expense) benefit	8,581			1,559			(238		)	—			9,902
	Net income (loss)	$	(18,232	)	$	(2,895	)	$	442		$	2,453		$	(18,232	)
	Condensed Consolidating Statement of Operations and Comprehensive Income (Loss)
	Three Months Ended March 31, 2014
	(Unaudited)
	(Dollars in thousands)
		Issuer			Guarantor			Non-Guarantor			Adjustments/			Consolidated
					Subsidiaries			Subsidiary			Eliminations
	Total revenue	$	81,968		$	41,814		$	823		$	—		$	124,605
	Costs and expenses	59,393			30,126			507			—			90,026
	Operating income (loss)	22,575			11,688			316			—			34,579
	Other income (expense)	(17,272		)	235			315			—			(16,722		)
	Equity in earnings of subsidiaries	8,160			—			—			(8,160		)	—
Income tax (expense) benefit	(2,071		)	(4,173		)	(221		)	—			(6,465		)
Net income (loss)	$	11,392		$	7,750		$	410		$	(8,160	)	$	11,392
Condensed Consolidating Statement of Cash Flows
Three Months Ended March 31, 2015
(Unaudited)
(Dollars in thousands)
	Issuer			Guarantor			Non-Guarantor			Adjustments/			Consolidated
				Subsidiaries			Subsidiary			Eliminations
Operating activities	$	22,675		$	(4,260	)	$	1,076		$	95		$	19,586
Investing activities	(81,921		)	116			(171		)	(95		)	(82,071		)
Financing activities	40,338			1,915			(253		)	—			42,000
Net increase (decrease) in cash and cash equivalents	(18,908		)	(2,229		)	652			—			(20,485		)
Cash at beginning of period	21,217			6,693			106			—			28,016
Cash at end of period	$	2,309		$	4,464		$	758		$	—		$	7,531
Condensed Consolidating Statement of Cash Flows
Three Months Ended March 31, 2014
(Unaudited)
(Dollars in thousands)
	Issuer			Guarantor			Non-Guarantor			Adjustments/			Consolidated
				Subsidiaries			Subsidiary			Eliminations
Operating activities	$	53,573		$	23,309		$	1,532		$	889		$	79,303
Investing activities	(18,322		)	(5,910		)	(1,592		)	(889		)	(26,713		)
Financing activities	(20,844		)	(19,232		)	76			—			(40,000		)
Net increase (decrease) in cash and cash equivalents	14,407			(1,833		)	16			—			12,590
Cash at beginning of period	19,693			6,886			44			—			26,623
Cash at end of period	$	34,100		$	5,053		$	60		$	—		$	39,213

Subsequent_Events

Subsequent Events	3 Months Ended
	Mar. 31, 2015
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events
	We have evaluated events and transactions that occurred after the balance sheet date of March 31, 2015 and have determined that no other events or transactions have occurred that would require recognition in the consolidated financial statements or disclosures in these notes to the consolidated financial statements.

Presentation_Presentation_Poli

Presentation Presentation (Policies)	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Recent Accounting Pronouncements	In April 2015, the FASB issued ASU No. 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs,” that requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this Update. An entity is required to apply ASU 2015-03 for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. An entity should apply ASU 2015-03 on a retrospective basis, wherein the balance sheet of each individual period presented should be adjusted to reflect the period-specific effects of applying the new guidance. Upon transition, an entity is required to comply with the applicable disclosures for a change in an accounting principle. These disclosures include the nature of and reason for the change in accounting principle, the transition method, a description of the prior-period information that has been retrospectively adjusted, and the effect of the change on the financial statement line items (that is, debt issuance cost asset and the debt liability). We are evaluating the impact that this new guidance will have on our consolidated financial statements.
	In May 2014, the Financial Accounting Standards Board (the “FASB”) issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” that outlines a new, single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance, including industry-specific guidance. This new revenue recognition model provides a five-step analysis in determining when and how revenue is recognized. The new model will require revenue recognition to depict the transfer of promised goods or services to customers in an amount that reflects the consideration a company expects to receive in exchange for those goods or services. An entity is required to apply ASU 2014-09 for annual reporting periods beginning after December 15, 2016, and interim periods within those annual periods. An entity can apply ASU 2014-09 using either a full retrospective method, meaning the standard is applied to all of the periods presented, or a modified retrospective method, meaning the cumulative effect of initially applying the standard is recognized in the most current period presented in the financial statements. We are evaluating the impact that this new guidance will have on our consolidated financial statements.

LongTerm_Debt_Tables

Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Schedule of long-term debt	Long-term debt consists of the following:
		March 31,		December 31,
		2015		2014
		(In thousands)
	7.75% Senior Notes due 2019, net of unamortized original issue discount of $288 at March 31, 2015 and $304 at December 31, 2014	$	599,712	$	599,696
	Revolving credit facility, due April 2019(a)	147,000		105,000
		$	746,712	$	704,696
	_______
	(a)	Renewed and extended in April 2014.

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Schedule of changes in asset retirement obligations	The following table reflects the changes in ARO during the three months ended March 31, 2015 and the year ended December 31, 2014:
		March 31,			December 31,
		2015			2014
		(In thousands)
	Beginning of period	$	45,697		$	49,981
	Additional ARO from new properties	248			1,209
	Sales or abandonments of properties	(484		)	(5,246		)
	Accretion expense	958			3,662
	Revisions of previous estimates	(188		)	(3,909		)
	End of period	$	46,231		$	45,697

Deferred_Revenue_from_Volumetr1

Deferred Revenue from Volumetric Production Payment (Tables)	3 Months Ended
	Mar. 31, 2015
Deferred Revenue Disclosure [Abstract]
Schedule of changes in deferred revenue from the VPP	The following table reflects the changes in the deferred revenue during the three months ended March 31, 2015 and the year ended December 31, 2014:
		March 31,			December 31,
		2015			2014
		(In thousands)
	Beginning of period	$	23,129		$	29,770
	Deferred revenue from VPP	258			1,067
	Amortization of deferred revenue from VPP	(1,778		)	(7,708		)
	End of period	$	21,609		$	23,129

Compensation_Plans_Tables

Compensation Plans (Tables)	3 Months Ended
	Mar. 31, 2015
Compensation Plans [Abstract]
Schedule of aggregate compensation under non-equity award plans reflected on the balance sheet	Accrued compensation under non-equity award plans is reflected in the accompanying consolidated balance sheets as detailed in the following schedule:
		March 31,		December 31,
		2015		2014
		(In thousands)
	Current liabilities:
	Accrued liabilities and other	$	2,128	$	2,317
	Non-current liabilities:
	Accrued compensation under non-equity award plans	19,369		17,866
	Total accrued compensation under non-equity award plans	$	21,497	$	20,183

Derivatives_Tables

Derivatives (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of information concerning the entity's net positions in open commodity derivatives	The following summarizes information concerning our net positions in open commodity derivatives applicable to periods subsequent to March 31, 2015.  The settlement prices of commodity derivatives are based on NYMEX futures prices.
	Swaps
		Oil
		MBbls			Price
	Production Period:
	2nd Quarter 2015	448			$	55.65
	3rd Quarter 2015	697			$	55.65
	4th Quarter 2015	592			$	55.65
		1,737
Schedule of effect of derivative instruments on the consolidated balance sheet	Effect of Derivative Instruments on the Consolidated Balance Sheets
		Fair Value of Derivative Instruments as of March 31, 2015
		Asset Derivatives						Liability Derivatives
		Balance Sheet						Balance Sheet
		Location		Fair Value				Location		Fair Value
				(In thousands)						(In thousands)
	Derivatives not designated as hedging instruments:
	Commodity derivatives	Fair value of derivatives:						Fair value of derivatives:
		Current		$	4,632			Current		$	—
		Non-current		—				Non-current		—
	Total			$	4,632					$	—
		Fair Value of Derivative Instruments as of December 31, 2014
		Asset Derivatives						Liability Derivatives
		Balance Sheet						Balance Sheet
		Location		Fair Value				Location		Fair Value
				(In thousands)						(In thousands)
	Derivatives not designated as hedging instruments:
	Commodity derivatives	Fair value of derivatives:						Fair value of derivatives:
		Current		$	—			Current		$	—
		Non-current		—				Non-current		—
	Total			$	—					$	—
Schedule of gross to net presentation reconciliation of derivative assets and liabilities	Gross to Net Presentation Reconciliation of Derivative Assets and Liabilities
		31-Mar-15
		Assets				Liabilities
		(In thousands)
	Fair value of derivatives — gross presentation	$	4,632			$	—
	Effects of netting arrangements	—				—
	Fair value of derivatives — net presentation	$	4,632			$	—
		31-Dec-14
		Assets				Liabilities
		(In thousands)
	Fair value of derivatives — gross presentation	$	—			$	—
	Effects of netting arrangements	—				—
	Fair value of derivatives — net presentation	$	—			$	—
Schedule of effect of derivative instruments on the consolidated statement of operations and Comprehensive Income (Loss)	Effect of Derivative Instruments Recognized in Earnings on the Consolidated Statements of Operations and Comprehensive Income (Loss)
			Amount of Gain or (Loss) Recognized in Earnings
			Three Months Ended
			March 31,
	Location of Gain or (Loss) Recognized in Earnings		2015				2014
			(In thousands)
	Derivatives not designated as hedging instruments:
	Commodity derivatives:
	Other income (expense) -
	Gain (loss) on derivatives		$	4,632			$	(5,041	)
	Total		$	4,632			$	(5,041	)

Fair_Value_of_Financial_Instru1

Fair Value of Financial Instruments (Tables)	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Schedule of financial assets and liabilities measured on a recurring basis	The fair value of all derivative contracts is reflected on the consolidated balance sheet as detailed in the following schedule:
		March 31,		December 31,
		2015		2014
		Significant Other
		Observable Inputs
	Description	(Level 2)
		(In thousands)
	Assets:
	Fair value of commodity derivatives	$	4,632	$	—
	Total assets	$	4,632	$	—
	Liabilities:
	Fair value of commodity derivatives	$	—	$	—
	Total liabilities	$	—	$	—
Schedule of comparison of fair value to the carrying value of the 2019 Senior Notes	Fair value is compared to the carrying value in the table below:
		31-Mar-15				31-Dec-14
		Carrying		Estimated		Carrying		Estimated
	Description	Amount		Fair Value		Amount		Fair Value
		(In thousands)
	7.75% Senior Notes due 2019	$	599,712	$	558,000	$	599,696	$	510,000

Other_Operating_Revenues_and_E1

Other Operating Revenues and Expenses (Tables)	3 Months Ended
	Mar. 31, 2015
Other Operating Revenues [Abstract]
Schedule of other operating revenues and expenses	Other operating revenues and expenses for the three months ended March 31, 2015 and March 31, 2014 are as follows:
		Three Months Ended
		March 31,
		2015			2014
		(In thousands)
	Other operating revenues:
	Gain on sales of assets	$	3,915		$	5,142
	Marketing revenue	23			382
	Total other operating revenues	$	3,938		$	5,524
	Other operating expenses:
	Loss on sales of assets	$	(61	)	$	(492	)
	Impairment of inventory	(783		)	(10		)
	Total other operating expenses	$	(844	)	$	(502	)

Costs_of_Oil_and_Gas_Propertie1

Costs of Oil and Gas Properties (Tables)	3 Months Ended
	Mar. 31, 2015
Oil and Gas Property, Successful Effort Method, Gross [Abstract]
Schedule of net capitalized costs for oil and gas properties	The following table sets forth the net capitalized costs for oil and gas properties as of March 31, 2015 and December 31, 2014.
		March 31,			December 31,
		2015			2014
		(In thousands)
	Proved properties	$	2,683,534		$	2,585,279
	Unproved properties	53,675			99,634
	Total capitalized costs	2,737,209			2,684,913
	Accumulated depletion	(1,472,112		)	(1,430,699		)
	Net capitalized costs	$	1,265,097		$	1,254,214

Segment_Information_Tables

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2015
Segment Reporting [Abstract]
Schedule of selected financial information regarding operating segments	The following tables present selected financial information regarding our operating segments for the three months ended March 31, 2015 and 2014:
	For the Three Months Ended
	31-Mar-15
	(Unaudited)					Contract			Intercompany			Consolidated
	(In thousands)		Oil and Gas			Drilling			Eliminations			Total
	Revenues		$	64,080		$	680		$	(618	)	$	64,142
	Depreciation, depletion and amortization (a)		42,076			3,204			(95		)	45,185
	Other operating expenses (b)		37,201			2,788			(850		)	39,139
	Interest expense		13,277			—			—			13,277
	Other (income) expense		(5,325		)	—			—			(5,325		)
	Income (loss) before income taxes		(23,149		)	(5,312		)	327			(28,134		)
	Income tax (expense) benefit		8,043			1,859			—			9,902
	Net income (loss)		$	(15,106	)	$	(3,453	)	$	327		$	(18,232	)
	Total assets		$	1,458,121		$	61,272		$	(42,459	)	$	1,476,934
	Additions to property and equipment		$	54,510		$	636		$	328		$	55,474
	For the Three Months Ended
	31-Mar-14
	(Unaudited)					Contract			Intercompany			Consolidated
	(In thousands)		Oil and Gas			Drilling			Eliminations			Total
	Revenues		$	117,720		$	13,420		$	(6,535	)	$	124,605
	Depreciation, depletion and amortization (a)		37,382			3,168			(889		)	39,661
	Other operating expenses (b)		45,447			9,914			(4,996		)	50,365
	Interest expense		12,521			—			—			12,521
	Other (income) expense		4,201			—			—			4,201
	Income (loss) before income taxes		18,169			338			(650		)	17,857
	Income tax (expense) benefit		(6,347		)	(118		)	—			(6,465		)
	Net income (loss)		$	11,822		$	220		$	(650	)	$	11,392
	Total assets		$	1,332,223		$	58,245		$	(27,638	)	$	1,362,830
	Additions to property and equipment		$	85,193		$	7,657		$	(651	)	$	92,199
	_______
	(a)	Includes impairment of property and equipment.
	(b)	Includes the following expenses: production, exploration, midstream services, drilling rig services, accretion of ARO, G&A and other operating expenses.

Guarantor_Financial_Informatio1

Guarantor Financial Information (Tables)	3 Months Ended
	Mar. 31, 2015
Guarantor Financial Information Disclosure [Abstract]
Schedule of Condensed Consolidating Balance Sheet	The financial information which follows sets forth our condensed consolidating financial statements as of and for the periods indicated.
	Condensed Consolidating Balance Sheet
	31-Mar-15
	(Unaudited)
	(Dollars in thousands)
		Issuer			Guarantor			Non-Guarantor			Adjustments/			Consolidated
					Subsidiaries			Subsidiary			Eliminations
	Current assets	$	115,996		$	297,375		$	1,034		$	(322,037	)	$	92,368
	Property and equipment, net	1,001,308			336,654			18,429			—			1,356,391
	Investments in subsidiaries	356,523			—			—			(356,523		)	—
	Other assets	14,859			13,316			—			—			28,175
	Total assets	$	1,488,686		$	647,345		$	19,463		$	(678,560	)	$	1,476,934
	Current liabilities	$	314,241		$	115,722		$	220		$	(322,494	)	$	107,689
	Non-current liabilities:
	Long-term debt	746,712			—			—			—			746,712
	Deferred income taxes	115,507			140,546			4,465			(105,361		)	155,157
	Other	38,482			49,148			184			—			87,814
		900,701			189,694			4,649			(105,361		)	989,683
	Equity	273,744			341,929			14,594			(250,705		)	379,562
	Total liabilities and equity	$	1,488,686		$	647,345		$	19,463		$	(678,560	)	$	1,476,934
	Condensed Consolidating Balance Sheet
	December 31, 2014
	(Dollars in thousands)
		Issuer			Guarantor			Non-Guarantor			Adjustments/			Consolidated
					Subsidiaries			Subsidiary			Eliminations
	Current assets	$	153,373		$	293,613		$	546		$	(314,912	)	$	132,620
	Property and equipment, net	986,110			344,174			18,600			—			1,348,884
	Investments in subsidiaries	359,777			—			—			(359,777		)	—
	Other assets	16,077			13,304			—			—			29,381
	Total assets	$	1,515,337		$	651,091		$	19,146		$	(674,689	)	$	1,510,885
	Current liabilities	$	352,889		$	113,746		$	586		$	(310,868	)	$	156,353
	Non-current liabilities:
	Long-term debt	704,696			—			—			—			704,696
	Deferred income taxes	129,105			141,130			4,227			(109,863		)	164,599
	Other	36,671			50,591			181			—			87,443
		870,472			191,721			4,408			(109,863		)	956,738
	Equity	291,976			345,624			14,152			(253,958		)	397,794
	Total liabilities and equity	$	1,515,337		$	651,091		$	19,146		$	(674,689	)	$	1,510,885
Schedule of Condensed Consolidating Statement of Operations and Comprehensive Income (Loss)	Condensed Consolidating Statement of Operations and Comprehensive Income (Loss)
	Three Months Ended March 31, 2015
	(Unaudited)
	(Dollars in thousands)
		Issuer			Guarantor			Non-Guarantor			Adjustments/			Consolidated
					Subsidiaries			Subsidiary			Eliminations
	Total revenue	$	45,688		$	18,042		$	412		$	—		$	64,142
	Costs and expenses	61,021			22,675			628			—			84,324
	Operating income (loss)	(15,333		)	(4,633		)	(216		)	—			(20,182		)
	Other income (expense)	(9,027		)	179			896			—			(7,952		)
	Equity in earnings of subsidiaries	(2,453		)	—			—			2,453			—
	Income tax (expense) benefit	8,581			1,559			(238		)	—			9,902
	Net income (loss)	$	(18,232	)	$	(2,895	)	$	442		$	2,453		$	(18,232	)
	Condensed Consolidating Statement of Operations and Comprehensive Income (Loss)
	Three Months Ended March 31, 2014
	(Unaudited)
	(Dollars in thousands)
		Issuer			Guarantor			Non-Guarantor			Adjustments/			Consolidated
					Subsidiaries			Subsidiary			Eliminations
	Total revenue	$	81,968		$	41,814		$	823		$	—		$	124,605
	Costs and expenses	59,393			30,126			507			—			90,026
	Operating income (loss)	22,575			11,688			316			—			34,579
	Other income (expense)	(17,272		)	235			315			—			(16,722		)
	Equity in earnings of subsidiaries	8,160			—			—			(8,160		)	—
	Income tax (expense) benefit	(2,071		)	(4,173		)	(221		)	—			(6,465		)
	Net income (loss)	$	11,392		$	7,750		$	410		$	(8,160	)	$	11,392
Schedule of Condensed Consolidating Statement of Cash Flows	Condensed Consolidating Statement of Cash Flows
	Three Months Ended March 31, 2015
	(Unaudited)
	(Dollars in thousands)
		Issuer			Guarantor			Non-Guarantor			Adjustments/			Consolidated
					Subsidiaries			Subsidiary			Eliminations
	Operating activities	$	22,675		$	(4,260	)	$	1,076		$	95		$	19,586
	Investing activities	(81,921		)	116			(171		)	(95		)	(82,071		)
	Financing activities	40,338			1,915			(253		)	—			42,000
	Net increase (decrease) in cash and cash equivalents	(18,908		)	(2,229		)	652			—			(20,485		)
	Cash at beginning of period	21,217			6,693			106			—			28,016
	Cash at end of period	$	2,309		$	4,464		$	758		$	—		$	7,531
	Condensed Consolidating Statement of Cash Flows
	Three Months Ended March 31, 2014
	(Unaudited)
	(Dollars in thousands)
		Issuer			Guarantor			Non-Guarantor			Adjustments/			Consolidated
					Subsidiaries			Subsidiary			Eliminations
	Operating activities	$	53,573		$	23,309		$	1,532		$	889		$	79,303
	Investing activities	(18,322		)	(5,910		)	(1,592		)	(889		)	(26,713		)
	Financing activities	(20,844		)	(19,232		)	76			—			(40,000		)
	Net increase (decrease) in cash and cash equivalents	14,407			(1,833		)	16			—			12,590
	Cash at beginning of period	19,693			6,886			44			—			26,623
	Cash at end of period	$	34,100		$	5,053		$	60		$	—		$	39,213

Nature_of_Operations_Details

Nature of Operations (Details)	3 Months Ended
	Mar. 31, 2015
Nature of Operations Disclosures [Abstract]
Percentage of outstanding common stock beneficially owned by Mr.William's	26.00%
Percentage of outstanding common stock owned by a partnership in which Mr. William's adult children are limited partners	25.00%

Presentation_Details

Presentation (Details)	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
The percentage of consolidated total assets and total revenues derived from oil and gas partnerships is less than	5.00%

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	1 Months Ended	3 Months Ended	1 Months Ended		12 Months Ended
	Apr. 30, 2011	Mar. 31, 2015	Apr. 30, 2014	Feb. 28, 2015	Dec. 31, 2014	Oct. 31, 2013	Mar. 31, 2011	Feb. 01, 2015	Nov. 30, 2014
			Bank
Long-Term Debt
Long-term debt		$746,712,000			704,696,000
7.75% Senior Notes due 2019
Long-Term Debt
Long-term debt		599,712,000			599,696,000
Aggregate principal amount of notes issued	50,000,000					250,000,000	300,000,000
Interest rate (as a percent)		7.75%			7.75%		7.75%
Original issue discount (as a percent)	1.00%
Unamortized original issue discount	500,000	288,000			304,000
Minimum ratio of EBITDA to consolidated interest expense		2.25
7.75% Senior Notes due 2019 | Beginning on April 1, 2016
Long-Term Debt
Redemption price of debt instrument (as a percent)		101.94%
7.75% Senior Notes due 2019 | On or after April 1, 2017
Long-Term Debt
Redemption price of debt instrument (as a percent)		100.00%
Revolving credit facility, due November 2015
Long-Term Debt
Long-term debt		147,000,000			105,000,000
Number of banks syndicated to provide for line of credit			16
Maximum borrowing capacity			1,000,000,000						600,000,000
Borrowing base								500,000,000
Aggregate commitment amount									500,000,000
Amount available under the revolving credit facility		347,100,000
Outstanding letters of credit		$5,900,000
Effective annual interest rate (as a percent)		2.00%
Number of consecutive quarters for which ratio of consolidated funded indebtedness to consolidated EBITDAX is required to be maintained		4
Revolving credit facility, due November 2015 | Minimum
Long-Term Debt
Percentage of adjusted engineered value of oil and gas interests serving as collateral					80.00%
Commitment fee on unused portion (as a percent)		0.38%
Current ratio		1
Covenant, senior debt to EBITDA, ratio				2.5
Covenant, interest to EBITDA, ratio				1.5
Revolving credit facility, due November 2015 | Maximum
Long-Term Debt
Number of equal monthly installments to prepay the deficiency			5
Commitment fee on unused portion (as a percent)		0.50%
Consolidated funded indebtedness to consolidated EBITDA ratio		4
Revolving credit facility, due November 2015 | LIBOR
Long-Term Debt
Variable rate basis		LIBOR
Revolving credit facility, due November 2015 | LIBOR | Minimum
Long-Term Debt
Applicable margin (as a percent)		1.75%
Revolving credit facility, due November 2015 | LIBOR | Maximum
Long-Term Debt
Applicable margin (as a percent)		2.75%
Revolving credit facility, due November 2015 | Prime rate
Long-Term Debt
Variable rate basis		prime rate
Revolving credit facility, due November 2015 | Federal funds rate
Long-Term Debt
Variable rate basis		federal funds rate
Applicable margin (as a percent)		0.50%
Revolving credit facility, due November 2015 | Base rate | Minimum
Long-Term Debt
Applicable margin (as a percent)		0.75%
Revolving credit facility, due November 2015 | Base rate | Maximum
Long-Term Debt
Applicable margin (as a percent)		1.75%
Revolving credit facility, due November 2015 | One-month LIBOR
Long-Term Debt
Variable rate basis		one-month LIBOR
Applicable margin (as a percent)		1.00%

Sale_of_Assets_Details

Sale of Assets (Details) (USD $)	1 Months Ended				3 Months Ended
	Mar. 31, 2015	Jun. 30, 2014	Mar. 31, 2014	Feb. 28, 2014	Mar. 31, 2015	Mar. 31, 2014	Apr. 30, 2015
Sale Of Assets [Line Items]
Proceeds from sale of interests					$4,995,000	$68,979,000
Proceeds from sale of interest in wells and related leasehold interest			71,000,000
Escrow deposits related to property sales			6,800,000
Amount received out of escrow	131,000	4,300,000
Proceeds from sale of property				5,100,000
Martin County, TX | Wells and Related Equipment and Facilities
Sale Of Assets [Line Items]
Proceeds from sale of interests	2,900,000
Yoakum County, TX | Wells and Related Equipment and Facilities
Sale Of Assets [Line Items]
Proceeds from sale of interests	800,000
Subsequent Event
Sale Of Assets [Line Items]
Amount remaining in escrow							$2,400,000

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	3 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Changes in asset retirement obligations
Beginning of period	$45,697	$49,981	$49,981
Additional ARO from new properties	248		1,209
Sales or abandonments of properties	-484		-5,246
Accretion expense	958	886	3,662
Revisions of previous estimates	-188		-3,909
End of period	$46,231		$45,697

Deferred_Revenue_from_Volumetr2

Deferred Revenue from Volumetric Production Payment (Details) (USD $)	1 Months Ended	3 Months Ended		12 Months Ended
	Mar. 31, 2012	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
	partnership	MBoe
Deferred Revenue Arrangement [Line Items]
Number of limited partnerships involved in mergers	24
Remaining obligation (in MBOE)		349
Changes in deferred revenue from the VPP
Beginning of period		$23,129,000	$29,770,000	$29,770,000
Deferred revenue from VPP		258,000		1,067,000
Amortization of deferred revenue from VPP		-1,778,000	-2,010,000	-7,708,000
End of period		21,609,000		23,129,000
Southwest Royalties, Inc. | Limited partnerships
Deferred Revenue Arrangement [Line Items]
Upfront cash proceeds under VPP	44,400,000
Deferred future advances under VPP	4,700,000
Barrels of oil equivalents of future oil and gas production covered by a term overriding royalty interest conveyed to a third party under the terms of the VPP (in MBOE)	725

Compensation_Plans_Details

Compensation Plans (Details) (USD $)	3 Months Ended		1 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Jan. 31, 2007	Dec. 31, 2014	1-May-15
			well		award
Non-Equity Award Plans
Compensation expense recorded	$2,100,000	$4,700,000
Current liabilities:
Accrued liabilities and other	2,128,000			2,317,000
Non-current liabilities:
Accrued compensation under non-equity award plans	19,369,000			17,866,000
Total accrued compensation under non-equity award plans	$21,497,000			$20,183,000
APO Incentive Plan | Minimum
Non-Equity Award Plans
Subsequent revenues received by participants (as a percent)	99.00%
Subsequent expenses paid by participants (as a percent)	99.00%
Economic interests in specified wells drilled or acquired as part of the plan (as a percent)	5.00%
APO Incentive Plan | Maximum
Non-Equity Award Plans
Subsequent revenues received by participants (as a percent)	100.00%
Subsequent expenses paid by participants (as a percent)	100.00%
Economic interests in specified wells drilled or acquired as part of the plan (as a percent)	7.50%
APO Reward Plan
Non-Equity Award Plans
Number of specified areas in which awards granted	15
Quarterly bonus amount, percentage of after-payout cash flow from wells drilled or recompleted, one	7.00%
Quarterly bonus amount, percentage of after-payout cash flow from wells drilled or recompleted, two	10.00%
Number of awards with specified vesting date	15
Number of award fully vested	8
APO Reward Plan | Full vesting Date August 1, 2015
Non-Equity Award Plans
Number of award expected to vest	2
APO Reward Plan | Full Vesting Date, June 23, 2016
Non-Equity Award Plans
Number of award expected to vest	3
APO Reward Plan | Minimum
Non-Equity Award Plans
Vesting period	2 years
APO Reward Plan | Maximum
Non-Equity Award Plans
Vesting period	5 years
SWR Reward Plan
Non-Equity Award Plans
Percentage of working interest in well			22.50%
Number of wells, working interest			1
SWR Reward Plan | Full vesting date, October 25, 2011
Non-Equity Award Plans
Percentage of subsequent quarterly bonus amounts after full vesting date payable to participants			100.00%
SWR Reward Plan | Minimum
Non-Equity Award Plans
Vesting period	2 years
SWR Reward Plan | Maximum
Non-Equity Award Plans
Vesting period	5 years
Subsequent Event | APO Reward Plan | Full Vesting Date May 1, 2015
Non-Equity Award Plans
Number of award fully vested					2

Derivatives_Details

Derivatives (Details) (Commodity Derivatives, USD $)	Mar. 31, 2015
In Millions, unless otherwise specified
Derivatives
Sensitivity analysis, impact of $1 per barrel change in derivative fair values	$1.70
Oil
Derivatives
Notional amount	1,737
Oil | Swap, Second Quarter
Derivatives
Notional amount	448
Fixed price	55.65
Oil | Swap, Third Quarter
Derivatives
Notional amount	697
Fixed price	55.65
Oil | Swap, Fourth Quarter
Derivatives
Notional amount	592
Fixed price	55.65

Derivatives_Details_2

Derivatives (Details 2) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Effect of Derivative Instruments on the Consolidated Balance Sheets
Fair value of derivative assets, current	$4,632	$0
Asset Derivatives, Fair Value	4,632	0
Liability Derivatives, Fair Value	0	0
Assets
Fair value of derivatives-gross presentation	4,632	0
Effects of netting arrangements	0	0
Asset Derivatives, Fair Value	4,632	0
Liabilities
Fair value of derivatives-gross presentation	0	0
Effects of netting arrangements	0	0
Liability Derivatives, Fair Value	0	0
Commodity Derivatives | Nondesignated
Effect of Derivative Instruments on the Consolidated Balance Sheets
Fair value of derivative assets, current	4,632	0
Fair value of derivative assets, noncurrent	0	0
Asset Derivatives, Fair Value	4,632	0
Fair value of derivative liabilities, current	0	0
Fair value of derivative liabilities, noncurrent	0	0
Liability Derivatives, Fair Value	0	0
Assets
Asset Derivatives, Fair Value	4,632	0
Liabilities
Liability Derivatives, Fair Value	$0	$0

Derivatives_Details_3

Derivatives (Details 3) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Amount of Gain or (Loss) Recognized in Earnings
Gain (loss) on derivatives	$4,632	($5,041)
Commodity Derivatives | Nondesignated
Amount of Gain or (Loss) Recognized in Earnings
Gain (loss) on derivatives	$4,632	($5,041)

Fair_Value_of_Financial_Instru2

Fair Value of Financial Instruments (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Assets:
Fair value of commodity derivatives	$4,632	$0
Liabilities:
Fair value of commodity derivatives	0	0
Recurring | Significant Other Observable Inputs (Level 2)
Assets:
Fair value of commodity derivatives	4,632	0
Total assets	4,632	0
Liabilities:
Fair value of commodity derivatives	0	0
Total liabilities	$0	$0

Fair_Value_of_Financial_Instru3

Fair Value of Financial Instruments (Details 2) (Level 1, 7.75% Senior Notes due 2019, USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Carrying Amount
Fair Value of Other Financial Instruments
Long-term debt	$599,712	$599,696
Estimated Fair Value
Fair Value of Other Financial Instruments
Long-term debt	$558,000	$510,000

Income_Taxes_Details

Income Taxes (Details)	3 Months Ended
	Mar. 31, 2015
Income Tax Disclosure [Abstract]
Effective federal and state income tax expense rate (as a percent)	35.20%
Statutory federal rate (as a percent)	35.00%

Other_Operating_Revenues_and_E2

Other Operating Revenues and Expenses (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Other Operating Revenues [Abstract]
Gain on sales of assets	$3,915	$5,142
Marketing revenue	23	382
Total other operating revenues	3,938	5,524
Other Operating Expense [Abstract]
Loss on sales of assets	-61	-492
Impairment of inventory	-783	-10
Total other operating expenses	($844)	($502)

Investment_in_Dalea_Investment1

Investment in Dalea Investment Group, LLC (Details) (Dalea Investment Group, LLC, USD $)	1 Months Ended	3 Months Ended
	Jun. 30, 2012	Mar. 31, 2015	Mar. 31, 2014
Dalea Investment Group, LLC
Investment in Dalea Investment Group, LLC
Note receivable cancelled	$11,000,000
Non-controlling Membership interest (as a percent)	7.66%
Recorded investment		11,000,000
Cost-method Investments, Realized Gain (Loss)		$900,000	$0

Costs_of_Oil_and_Gas_Propertie2

Costs of Oil and Gas Properties (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Oil and Gas Property, Successful Effort Method, Gross [Abstract]
Proved properties	$2,683,534	$2,585,279
Unproved properties	53,675	99,634
Total capitalized costs	2,737,209	2,684,913
Accumulated depletion	-1,472,112	-1,430,699
Net capitalized costs	$1,265,097	$1,254,214

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	1 Months Ended		12 Months Ended	1 Months Ended
In Millions, unless otherwise specified	Jul. 31, 2013	Oct. 31, 2013	Dec. 31, 2013	Nov. 30, 2013	Jun. 30, 2013	Apr. 30, 2011
	lawsuit			lawsuit	plaintiff
Loss Contingencies [Line Items]
Number Of lawsuits	3
BMT O&G TX, L.P.
Loss Contingencies [Line Items]
Loss contingency settlement amount		$2.90
Legal fees		0.8
Gain (loss) related to litigation settlement			-1.4
SELFPA
Loss Contingencies [Line Items]
Number Of lawsuits	1
Number of defendants	95
Plaquemines Parish
Loss Contingencies [Line Items]
Number Of lawsuits				2
Environmental Remediation Case 2001
Loss Contingencies [Line Items]
Loss contingency, damages sought, value						8
Loss contingency settlement amount					0.8
Loss contingency, settlement amount paid			$0.70		$0.70
Loss contingency, number of plaintiffs opting out					1

Impairment_of_Property_and_Equ1

Impairment of Property and Equipment (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
	method
Property, Plant and Equipment Impairment or Disposal [Abstract]
Number of methods to determine fair value of impaired property	3
Impairment of property and equipment	$2,531,000	$3,406,000
Provisions for impairment of unproved properties	$200,000	$3,500,000

Segment_Information_Details

Segment Information (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
	segment
Segment Reporting [Abstract]
Number of reportable operating segments	2
Segment Information
Revenues	$64,142	$124,605
Depreciation, depletion and amortization	45,185	39,661
Other operating expenses	39,139	50,365
Interest expense	13,277	12,521
Other (income) expense	-5,325	4,201
Income (loss) before income taxes	-28,134	17,857
Income tax (expense) benefit	9,902	-6,465
Net income (loss)	-18,232	11,392
Total assets	1,476,934	1,362,830	1,510,885
Additions to property and equipment	55,474	92,199
Oil and Gas
Segment Information
Revenues	64,080	117,720
Depreciation, depletion and amortization	42,076	37,382
Other operating expenses	37,201	45,447
Interest expense	13,277	12,521
Other (income) expense	-5,325	4,201
Income (loss) before income taxes	-23,149	18,169
Income tax (expense) benefit	8,043	-6,347
Net income (loss)	-15,106	11,822
Total assets	1,458,121	1,332,223
Additions to property and equipment	54,510	85,193
Contract Drilling
Segment Information
Revenues	680	13,420
Depreciation, depletion and amortization	3,204	3,168
Other operating expenses	2,788	9,914
Interest expense	0	0
Other (income) expense	0	0
Income (loss) before income taxes	-5,312	338
Income tax (expense) benefit	1,859	-118
Net income (loss)	-3,453	220
Total assets	61,272	58,245
Additions to property and equipment	636	7,657
Intercompany Eliminations
Segment Information
Revenues	-618	-6,535
Depreciation, depletion and amortization	-95	-889
Other operating expenses	-850	-4,996
Interest expense	0	0
Other (income) expense	0	0
Income (loss) before income taxes	327	-650
Income tax (expense) benefit	0	0
Net income (loss)	327	-650
Total assets	-42,459	-27,638
Additions to property and equipment	$328	($651)

Guarantor_Financial_Informatio2

Guarantor Financial Information (Details) (2019 Senior Notes, USD $)	Oct. 31, 2013	Apr. 30, 2011	Mar. 31, 2011
Performance and payment guaranteed
Aggregate principal amount of notes issued	$250,000,000	$50,000,000	$300,000,000
Guarantor Subsidiaries | Guarantee on senior notes
Performance and payment guaranteed
Aggregate principal amount of notes issued	$250,000,000	$350,000,000

Guarantor_Financial_Informatio3

Guarantor Financial Information (Details 2) (USD $)	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014
In Thousands, unless otherwise specified
Condensed consolidating financial statements
Current assets	$92,368	$132,620
Property and equipment, net	1,356,391	1,348,884
Investments in subsidiaries	0	0
Other assets	28,175	29,381
TOTAL ASSETS	1,476,934	1,510,885	1,362,830
Current liabilities	107,689	156,353
Non-current liabilities:
Long-term debt	746,712	704,696
Deferred income taxes	155,157	164,599
Other	87,814	87,443
Total non-current liabilities	989,683	956,738
Equity	379,562	397,794
Total liabilities and equity	1,476,934	1,510,885
Issuer
Condensed consolidating financial statements
Current assets	115,996	153,373
Property and equipment, net	1,001,308	986,110
Investments in subsidiaries	356,523	359,777
Other assets	14,859	16,077
TOTAL ASSETS	1,488,686	1,515,337
Current liabilities	314,241	352,889
Non-current liabilities:
Long-term debt	746,712	704,696
Deferred income taxes	115,507	129,105
Other	38,482	36,671
Total non-current liabilities	900,701	870,472
Equity	273,744	291,976
Total liabilities and equity	1,488,686	1,515,337
Guarantor Subsidiaries
Condensed consolidating financial statements
Current assets	297,375	293,613
Property and equipment, net	336,654	344,174
Investments in subsidiaries	0	0
Other assets	13,316	13,304
TOTAL ASSETS	647,345	651,091
Current liabilities	115,722	113,746
Non-current liabilities:
Long-term debt	0	0
Deferred income taxes	140,546	141,130
Other	49,148	50,591
Total non-current liabilities	189,694	191,721
Equity	341,929	345,624
Total liabilities and equity	647,345	651,091
Non-Guarantor Subsidiaries
Condensed consolidating financial statements
Current assets	1,034	546
Property and equipment, net	18,429	18,600
Investments in subsidiaries	0	0
Other assets	0	0
TOTAL ASSETS	19,463	19,146
Current liabilities	220	586
Non-current liabilities:
Long-term debt	0	0
Deferred income taxes	4,465	4,227
Other	184	181
Total non-current liabilities	4,649	4,408
Equity	14,594	14,152
Total liabilities and equity	19,463	19,146
Adjustments/Eliminations
Condensed consolidating financial statements
Current assets	-322,037	-314,912
Property and equipment, net	0	0
Investments in subsidiaries	-356,523	-359,777
Other assets	0	0
TOTAL ASSETS	-678,560	-674,689
Current liabilities	-322,494	-310,868
Non-current liabilities:
Long-term debt	0	0
Deferred income taxes	-105,361	-109,863
Other	0	0
Total non-current liabilities	-105,361	-109,863
Equity	-250,705	-253,958
Total liabilities and equity	($678,560)	($674,689)

Guarantor_Financial_Informatio4

Guarantor Financial Information (Details 3) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Condensed consolidating financial statements
Total revenue	$64,142	$124,605
Costs and expenses	84,324	90,026
Operating income (loss)	-20,182	34,579
Other income (expense)	-7,952	-16,722
Equity in earnings of subsidiaries	0	0
Income tax (expense) benefit	9,902	-6,465
Net income (loss)	-18,232	11,392
Issuer
Condensed consolidating financial statements
Total revenue	45,688	81,968
Costs and expenses	61,021	59,393
Operating income (loss)	-15,333	22,575
Other income (expense)	-9,027	-17,272
Equity in earnings of subsidiaries	-2,453	8,160
Income tax (expense) benefit	8,581	-2,071
Net income (loss)	-18,232	11,392
Guarantor Subsidiaries
Condensed consolidating financial statements
Total revenue	18,042	41,814
Costs and expenses	22,675	30,126
Operating income (loss)	-4,633	11,688
Other income (expense)	179	235
Equity in earnings of subsidiaries	0	0
Income tax (expense) benefit	1,559	-4,173
Net income (loss)	-2,895	7,750
Non-Guarantor Subsidiaries
Condensed consolidating financial statements
Total revenue	412	823
Costs and expenses	628	507
Operating income (loss)	-216	316
Other income (expense)	896	315
Equity in earnings of subsidiaries	0	0
Income tax (expense) benefit	-238	-221
Net income (loss)	442	410
Adjustments/Eliminations
Condensed consolidating financial statements
Total revenue	0	0
Costs and expenses	0	0
Operating income (loss)	0	0
Other income (expense)	0	0
Equity in earnings of subsidiaries	2,453	-8,160
Income tax (expense) benefit	0	0
Net income (loss)	$2,453	($8,160)

Guarantor_Financial_Informatio5

Guarantor Financial Information (Details 4) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Condensed consolidating financial statements
Operating activities	$19,586	$79,303
Investing activities	-82,071	-26,713
Financing activities	42,000	-40,000
Net increase (decrease) in cash and cash equivalents	-20,485	12,590
Beginning of period	28,016	26,623
End of period	7,531	39,213
Issuer
Condensed consolidating financial statements
Operating activities	22,675	53,573
Investing activities	-81,921	-18,322
Financing activities	40,338	-20,844
Net increase (decrease) in cash and cash equivalents	-18,908	14,407
Beginning of period	21,217	19,693
End of period	2,309	34,100
Guarantor Subsidiaries
Condensed consolidating financial statements
Operating activities	-4,260	23,309
Investing activities	116	-5,910
Financing activities	1,915	-19,232
Net increase (decrease) in cash and cash equivalents	-2,229	-1,833
Beginning of period	6,693	6,886
End of period	4,464	5,053
Non-Guarantor Subsidiaries
Condensed consolidating financial statements
Operating activities	1,076	1,532
Investing activities	-171	-1,592
Financing activities	-253	76
Net increase (decrease) in cash and cash equivalents	652	16
Beginning of period	106	44
End of period	758	60
Adjustments/Eliminations
Condensed consolidating financial statements
Operating activities	95	889
Investing activities	-95	-889
Financing activities	0	0
Net increase (decrease) in cash and cash equivalents	0	0
Beginning of period	0	0
End of period	$0	$0