Rosetta Resources 10-Q 4 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Jun. 30, 2014	Jul. 25, 2014
Document And Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Jun-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'
Trading Symbol	'ROSE	'
Entity Registrant Name	'ROSETTA RESOURCES INC.	'
Entity Central Index Key	'0001340282	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	61,481,038

Consolidated_Balance_Sheet

Consolidated Balance Sheet (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$28,194	$193,784
Accounts receivable	137,518	122,677
Derivative instruments	'	4,307
Prepaid expenses	7,186	9,860
Deferred income taxes	25,016	27,976
Other current assets	4,604	1,284
Total current assets	202,518	359,888
Oil and natural gas properties using the full cost method of accounting:	'	'
Proved properties	4,937,235	3,951,397
Unproved/unevaluated properties, not subject to amortization	511,762	755,438
Gathering systems and compressor stations	262,424	168,730
Other fixed assets	28,316	26,362
Total property and equipment, gross	5,739,737	4,901,927
Accumulated depreciation, depletion and amortization, including impairment	-2,185,100	-2,020,879
Total property and equipment, net	3,554,637	2,881,048
Other assets:	'	'
Debt issuance costs	29,050	25,602
Derivative instruments	'	5,458
Other long-term assets	326	4,622
Total other assets	29,376	35,682
Total assets	3,786,531	3,276,618
Current liabilities:	'	'
Accounts payable and accrued liabilities	252,674	190,950
Royalties and other payables	94,166	78,264
Derivative instruments	33,742	4,913
Total current liabilities	380,582	274,127
Long-term liabilities:	'	'
Derivative instruments	21,368	433
Long-term debt	1,800,000	1,500,000
Deferred income taxes	159,968	136,407
Other long-term liabilities	21,015	17,317
Total liabilities	2,382,933	1,928,284
Commitments and Contingencies (Note 9)	'	'
Stockholders' equity:	'	'
Preferred stock, $0.001 par value; authorized 5,000,000 shares; no shares issued in 2014 or 2013	0	0
Common stock, $0.001 par value; authorized 150,000,000 shares; issued 62,260,461 shares and 62,032,162 shares at June 30, 2014 and December 31, 2013, respectively	62	61
Additional paid-in capital	1,190,788	1,182,672
Treasury stock, at cost; 781,843 shares and 724,755 shares at June 30, 2014 and December 31, 2013, respectively	-27,138	-24,592
Accumulated other comprehensive loss	-102	-108
Retained earnings	239,988	190,301
Total stockholders' equity	1,403,598	1,348,334
Total liabilities and stockholders' equity	$3,786,531	$3,276,618

Consolidated_Balance_Sheet_Par

Consolidated Balance Sheet (Parenthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Statement Of Financial Position [Abstract]	'	'
Preferred stock, par value	$0.00	$0.00
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, shares issued	0	0
Common stock, par value	$0.00	$0.00
Common stock, shares authorized	150,000,000	150,000,000
Common stock, shares issued	62,260,461	62,032,162
Treasury stock, shares	781,843	724,755

Consolidated_Statement_of_Oper

Consolidated Statement of Operations (Unaudited) (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues:	'	'	'	'
Oil sales	$162,703	$102,895	$294,380	$212,947
NGL sales	55,442	46,918	110,737	93,379
Natural gas sales	52,140	40,657	103,519	74,233
Derivative instruments	-49,395	46,050	-73,180	34,081
Total revenues	220,890	236,520	435,456	414,640
Operating costs and expenses:	'	'	'	'
Lease operating expense	25,064	11,217	44,585	20,128
Treating and transportation	18,618	18,520	39,295	33,607
Taxes, other than income	12,259	8,735	22,465	16,390
Depreciation, depletion and amortization	90,640	47,837	165,415	92,467
General and administrative costs	21,667	18,508	41,205	34,040
Total operating costs and expenses	168,248	104,817	312,965	196,632
Operating income	52,642	131,703	122,491	218,008
Other expense (income):	'	'	'	'
Interest expense, net of interest capitalized	17,327	13,033	32,617	19,102
Interest income	-1	'	-13	'
Other expense	12,496	471	12,647	441
Total other expense	29,822	13,504	45,251	19,543
Income before provision for income taxes	22,820	118,199	77,240	198,465
Income tax expense	8,376	42,847	27,553	69,633
Net income	$14,444	$75,352	$49,687	$128,832
Earnings per share:	'	'	'	'
Basic	$0.24	$1.28	$0.81	$2.31
Diluted	$0.23	$1.27	$0.81	$2.29
Weighted average shares outstanding:	'	'	'	'
Basic	61,452	58,990	61,416	55,879
Diluted	61,617	59,201	61,599	56,165

Consolidated_Statement_of_Comp

Consolidated Statement of Comprehensive Income (Unaudited) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Statement Of Income And Comprehensive Income [Abstract]	'	'	'	'
Net income	$14,444	$75,352	$49,687	$128,832
Other comprehensive income (loss):	'	'	'	'
Amortization of accumulated other comprehensive gain (loss) related to de-designated hedges, net of income taxes of ($1) and ($155) for the three and six months ended June 30, 2013, respectively	'	1	'	272
Postretirement medical benefits prior service benefit (cost), net of income taxes of ($2) and ($3) for the three months ended June 30, 2014 and 2013, respectively, ($4) and $101 for the six months ended June 30, 2014 and 2013, respectively	3	6	6	-179
Other comprehensive income (loss)	3	7	6	93
Comprehensive income	$14,447	$75,359	$49,693	$128,925

Consolidated_Statement_of_Comp1

Consolidated Statement of Comprehensive Income (Unaudited) (Parenthetical) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Statement Of Income And Comprehensive Income [Abstract]	'	'	'	'
Amortization of accumulated other comprehensive gain (loss) related to de-designated hedges, income taxes	'	($1)	'	($155)
Postretirement medical benefits prior service cost, income tax benefit	($2)	($3)	($4)	$101

Consolidated_Statement_of_Cash

Consolidated Statement of Cash Flows (Unaudited) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Cash flows from operating activities:	'	'
Net income	$49,687	$128,832
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	165,415	92,467
Deferred income taxes	26,521	67,890
Amortization of deferred loan fees recorded as interest expense	1,900	6,827
Loss on debt extinguishment	3,101	'
Stock-based compensation expense	7,393	4,893
Loss (gain) due to change in fair value of derivative instruments	59,529	-28,790
Change in operating assets and liabilities:	'	'
Accounts receivable	-14,840	-12,330
Prepaid expenses	2,578	668
Other current assets	-3,320	63
Long-term assets	46	'
Accounts payable and accrued liabilities	-15,041	8,412
Royalties and other payables	15,901	12,140
Other long-term liabilities	810	3,164
Excess tax benefit from share-based awards	'	-2,697
Net cash provided by operating activities	299,680	281,539
Cash flows from investing activities:	'	'
Acquisitions of oil and gas assets	-79,020	-940,982
Additions to oil and gas assets	-675,835	-345,606
Disposals of oil and gas assets	8	-1,724
Net cash used in investing activities	-754,847	-1,288,312
Cash flows from financing activities:	'	'
Borrowings on Credit Facility	550,000	420,000
Payments on Credit Facility	-550,000	-440,000
Issuance of Senior Notes	500,000	700,000
Retirement of Senior Notes	-200,000	'
Proceeds from issuance of common stock	'	329,152
Deferred loan fees	-8,354	-18,004
Proceeds from stock options exercised	376	2,674
Purchases of treasury stock	-2,546	-6,723
Excess tax benefit from share-based awards	101	2,697
Net cash provided by financing activities	289,577	989,796
Net decrease in cash	-165,590	-16,977
Cash and cash equivalents, beginning of period	193,784	36,786
Cash and cash equivalents, end of period	28,194	19,809
Supplemental disclosures:	'	'
Capital expenditures included in Accounts payable and accrued liabilities	$195,400	$94,001

Consolidated_Statement_of_Stoc

Consolidated Statement of Stockholders' Equity (Unaudited) (USD $)	Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Treasury Stock [Member]	Accumulated Other Comprehensive Loss [Member]	Retained Earnings [Member]
In Thousands, except Share data
Balance at December 31, 2013 at Dec. 31, 2013	$1,348,334	$61	$1,182,672	($24,592)	($108)	$190,301
Balance, Treasury Stock, Shares at Dec. 31, 2013	724,755	'	'	724,755	'	'
Balance, Common Stock Shares at Dec. 31, 2013	62,032,162	62,032,162	'	'	'	'
Excess tax benefit from share-based awards	101	'	101	'	'	'
Stock options exercised	377	1	376	'	'	'
Stock options exercised, shares	'	19,000	'	'	'	'
Treasury stock-employee tax payment	-2,546	'	'	-2,546	'	'
Treasury Stock, Shares, Acquired	'	'	'	57,088	'	'
Stock-based compensation	7,639	'	7,639	'	'	'
Vesting of restricted stock	'	'	'	'	'	'
Vesting of restricted stock, Shares	'	209,299	'	'	'	'
Comprehensive income	49,693	'	'	'	6	49,687
Balance at June 30, 2014 at Jun. 30, 2014	$1,403,598	$62	$1,190,788	($27,138)	($102)	$239,988
Balance, Treasury Stock, Shares at Jun. 30, 2014	781,843	'	'	781,843	'	'
Balance, Common Stock, Shares at Jun. 30, 2014	62,260,461	62,260,461	'	'	'	'

Organization_and_Operations_of

Organization and Operations of the Company	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Organization and Operations of the Company	'
	(1) Organization and Operations of the Company
	Nature of Operations. Rosetta Resources Inc. (together with its consolidated subsidiaries, the “Company”) is an independent exploration and production company engaged in the acquisition and development of onshore energy resources in the United States of America. The Company’s operations are located in the Eagle Ford shale in South Texas and the Permian Basin in West Texas.
	These interim financial statements have not been audited. However, in the opinion of management, all adjustments, consisting of normal recurring adjustments necessary to fairly state the financial statements, have been included. Results of operations for interim periods are not necessarily indicative of the results of operations that may be expected for the entire year. In addition, these financial statements have been prepared in accordance with the instructions to Form 10-Q and, therefore, do not include all disclosures required for financial statements prepared in conformity with accounting principles generally accepted in the U.S. (“GAAP”). These financial statements and notes should be read in conjunction with the Company’s audited Consolidated Financial Statements and the notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013 (“2013 Annual Report”).

Summary_of_Significant_Account

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	(2) Summary of Significant Accounting Policies
	The Company has provided a discussion of significant accounting policies, estimates and judgments in its 2013 Annual Report. There have been no changes to the Company’s significant accounting policies since December 31, 2013.
	Recent Accounting Developments
	In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers. The ASU will supersede most of the existing revenue recognition requirements in GAAP and will require entities to recognize revenue at an amount that reflects the consideration to which the Company expects to be entitled in exchange for transferring goods or services to a customer. The new standard also requires disclosures sufficient to enable users to understand an entity’s nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The pronouncement is effective for annual and interim reporting periods beginning after December 15, 2016, and is to be applied retrospectively, with early application not permitted. This guidance is not expected to have a material impact on the Company’s consolidated financial position, results of operations, or cash flows.

Property_and_Equipment

Property and Equipment	6 Months Ended
	Jun. 30, 2014
Extractive Industries [Abstract]	'
Property and Equipment	'
	(3) Property and Equipment
	The Company’s Total property and equipment, net consists of the following:
			June 30, 2014			December 31, 2013
			(In thousands)
	Proved properties		$	4,937,235		$	3,951,397
	Unproved/unevaluated properties			511,762			755,438
	Gathering systems and compressor stations			262,424			168,730
	Other fixed assets			28,316			26,362
	Total			5,739,737			4,901,927
	Less: Accumulated depreciation, depletion and amortization			(2,185,100	)		(2,020,879	)
	Total property and equipment, net		$	3,554,637		$	2,881,048
	Acquisitions
	2014 Permian Acquisition. On December 30, 2013, the Company entered into a definitive agreement with several private parties to acquire Delaware Basin assets covering 5,034 net acres located in Reeves County (the “2014 Permian Acquisition”). These assets include 13 gross producing wells, of which 11 are operated by the Company. The Company completed the 2014 Permian Acquisition on February 28, 2014, with an effective date of December 1, 2013, for total cash consideration of $83.2 million, subject to further customary post-closing adjustments.
	Gates Ranch Acquisition. In the second quarter of 2013, the Company acquired the remaining 10% working interest in certain producing wells along with a third party’s option to participate in future wells in certain leases of its Gates Ranch leasehold located in the Eagle Ford shale (the “Gates Acquisition”) in Webb County for total cash consideration of approximately $128.1 million. The transaction closed on June 5, 2013 (the “Gates Acquisition Date”) and was financed with borrowings under the Company’s senior secured revolving credit facility (the “Credit Facility”), as described in Note 7 – Debt and Credit Agreements. As of the Gates Acquisition Date, the Company owns a 100% working interest in the entire Gates Ranch leasehold.
	2013 Permian Acquisition. On March 14, 2013, the Company entered into a purchase and sale agreement with Comstock Oil & Gas, LP to purchase producing and undeveloped oil and natural gas interests in the Permian Basin in Gaines and Reeves Counties, Texas (the “2013 Permian Acquisition”). The Company completed the 2013 Permian Acquisition on May 14, 2013, with an effective date of January 1, 2013, for total cash consideration of $825.2 million. The 2013 Permian Acquisition was financed with the proceeds from the Company’s issuance of the 5.625% Senior Notes, as described in Note 7 – Debt and Credit Agreements, and the common stock offering described in Note 10 – Equity. In connection with the 2013 Permian Acquisition and related financings, the Company incurred total transaction costs of approximately $31.0 million, including (i) $5.6 million of commitment fees and related expenses associated with a bridge credit facility (“Bridge Credit Facility”), which were recorded as Interest expense since the Company did not borrow under the Bridge Credit Facility, (ii) $10.0 million of debt issuance costs paid in connection with the issuance of the 5.625% Senior Notes, which were deferred and are being amortized over the term of these senior notes, (iii) $13.1 million of equity issuance costs and related expenses associated with the common stock offering, which were reflected as a reduction of equity proceeds, and (iv) $2.3 million of consulting, investment, advisory, legal and other acquisition-related fees, which were expensed and are included in General and administrative costs.
	The above transactions were accounted for under the acquisition method of accounting, whereby each respective purchase price was allocated to the assets acquired and liabilities assumed based on their estimated fair values, with any excess of the purchase price over the estimated fair value of the identifiable net assets acquired recorded as goodwill (or shortfall of purchase price versus net fair value recorded as bargain purchase). Based on the final purchase price allocations for the Gates Acquisition and the 2013 Permian Acquisition and the preliminary purchase price allocation for the 2014 Permian Acquisition, no goodwill or bargain purchase was recognized. The final purchase price allocation for the 2013 Permian and Gates Ranch Acquisitions and the preliminary purchase price allocation for the 2014 Permian Acquisition, representing consideration paid, assets acquired and liabilities assumed as of the respective acquisition dates, are shown in the tables below.
	2014 Permian Acquisition
			Preliminary Total Purchase
			Price Allocation
			(In thousands)
	Cash consideration		$	83,172
	Fair value of assets acquired:
	Oil and natural gas properties
	Proved properties		$	61,598
	Unproved/unevaluated properties			21,867
	Total assets acquired		$	83,465
	Fair value of liabilities assumed:
	Asset retirement obligations		$	293
	Net assets acquired		$	83,172
	2013 Permian Acquisition and Gates Ranch Acquisition
			Final Total Purchase
			Price Allocation
			(In thousands)
	Cash consideration		$	953,242
	Fair value of assets acquired:
	Other fixed assets		$	600
	Oil and natural gas properties
	Proved properties			290,273
	Unproved/unevaluated properties			663,300
	Total assets acquired		$	954,173
	Fair value of liabilities assumed:
	Asset retirement obligations		$	931
	Net assets acquired		$	953,242
	The fair value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market and therefore represent Level 3 inputs. The fair values of oil and natural gas properties and asset retirement obligations were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of oil and natural gas properties included estimates of: (i) reserves, including risk adjustments for probable and possible reserves; (ii) production rates; (iii) future operating and development costs; (iv) future commodity prices; (v) future cash flows; and (vi) a market-based weighted average cost of capital rate. These inputs required significant judgments and estimates by the Company’s management at the time of the valuation and are the most sensitive and subject to change. See Note 5 – Fair Value Measurements for additional information.
	The results of operations attributable to the 2014 Permian Acquisition were included in the Company’s Consolidated Statement of Operations beginning on March 1, 2014 and increased Total revenues by $4.4 million and $5.9 million, respectively, and Operating income by $1.7 million and $2.3 million, respectively, for the three and six months ended June 30, 2014.
	The following unaudited pro forma information assumes the transactions and related financings for the 2013 Permian Acquisition and the Gates Acquisition occurred on January 1, 2012 and the 2014 Permian Acquisition occurred on January 1, 2013. The unaudited pro forma information includes the effects of issuing the 5.625% Senior Notes, the issuance of common stock in the equity offering and the use of proceeds from the debt and equity offerings as discussed above. The pro forma results of operations have been prepared by adjusting the Company’s historical results to include the historical results of the acquired assets based on information provided by the seller, the Company’s knowledge of the acquired properties and the impact of the Company’s purchase price allocation. The Company believes the assumptions used provide a reasonable basis for reflecting the pro forma significant effects directly attributable to the acquisitions and associated financings. The pro forma results of operations do not include any cost savings or other synergies that may result from the acquisitions, or any estimated costs that have been or will be incurred by the Company to integrate these assets. The pro forma information does not purport to represent what the Company’s results of operations would have been if the 2013 Permian Acquisition and Gates Acquisition had occurred on January 1, 2012 and the 2014 Permian Acquisition had occurred on January 1, 2013.
			Three Months Ended June 30,						Six Months Ended June 30,
			2014 (1)			2013			2014 (2)		2013
			(In thousands, except per share and share data)						(In thousands, except per share and share data)
	Total revenues		$	220,890		$	254,986		$	438,553	$	457,901
	Net income			14,444			73,625			50,480		126,350
	Earnings per share:
	Basic		$	0.24		$	1.21		$	0.82	$	2.07
	Diluted		$	0.23		$	1.2		$	0.82	$	2.06
	Weighted average shares outstanding:
	Basic			61,452			61,094			61,416		60,939
	Diluted			61,617			61,305			61,599		61,226
	-1	No pro forma adjustments were made for the period as all acquisitions and related financings are included in the Company’s historical results.
	-2	No pro forma adjustments were made related to the 2013 Permian Acquisition and Gates Acquisition for the period as the acquisitions are included in the Company’s historical results.
	Additional Disclosures about Property and Equipment
	The Company capitalizes internal costs directly identified with acquisition, exploration and development activities. The Company capitalized $2.1 million and $1.8 million of internal costs for the three months ended June 30, 2014 and 2013, respectively, and $3.7 million and $3.9 million for the six months ended June 30, 2014 and 2013, respectively.
	Oil and gas properties include unevaluated property costs of $511.8 million and $755.4 million as of June 30, 2014 and December 31, 2013, respectively, which are not being amortized. These amounts primarily represent acquisition costs of unproved properties and unevaluated exploration projects in which the Company owns a direct interest. Such costs are periodically evaluated for impairment, and upon evaluation or impairment are transferred to the Company’s full cost pool and amortized. During the six months ended June 30, 2014, the Company transferred $147.9 million of Permian acquisition costs to the full cost pool as a result of development activities in this area.
	Pursuant to full cost accounting rules, the Company must perform a ceiling test each quarter on its proved oil and natural gas assets within each separate cost center. All of the Company’s costs are included in one cost center because all of the Company’s operations are located in the United States. The Company’s ceiling test was calculated using trailing twelve-month, unweighted-average first-day-of-the-month prices for oil and natural gas as of June 30, 2014, which were based on a West Texas Intermediate oil price of $96.75 per Bbl and a Henry Hub natural gas price of $4.10 per MMBtu (adjusted for basis and quality differentials), respectively. Utilizing these prices, the calculated ceiling amount exceeded the net capitalized cost of oil and natural gas properties as of June 30, 2014, and as a result, no write-down was recorded. It is possible that a write-down of the Company’s oil and gas properties could occur in future periods in the event that oil and natural gas prices significantly decline or the Company experiences significant downward adjustments to its estimated proved reserves.

Commodity_Derivative_Contracts

Commodity Derivative Contracts	6 Months Ended
	Jun. 30, 2014
Derivative Instruments And Hedging Activities Disclosure [Abstract]	'
Commodity Derivative Contracts	'
	(4) Commodity Derivative Contracts
	The Company is exposed to various market risks, including volatility in oil, natural gas liquids (“NGL”) and natural gas prices, which are managed through derivative instruments. The level of derivative activity utilized depends on market conditions, operating strategies and available derivative prices. The Company utilizes various types of derivative instruments to manage commodity price risk, including fixed price swaps and costless collars. Forward contracts on various commodities are entered into to manage the price risk associated with forecasted sales of the Company’s oil, NGL and natural gas production.
	As of June 30, 2014, the following derivative contracts were outstanding with associated notional volumes and average underlying prices that represent hedged prices of commodities at various market locations:
	Product	Settlement				Derivative	Notional			Total			Average			Average
		Period				Instrument	Daily			Notional			Floor/Fixed Prices			Ceiling Prices
							Volume			Volume			per Bbl			per Bbl
							(Bbls)			(Bbls)
	Crude oil		2014			Costless Collar		3,000			552,000		$	83.33		$	109.63
	Crude oil		2014			Swap		6,000			1,104,000			93.13
	Crude oil		2015			Swap		11,000			4,015,000			89.51
	Crude oil		2016			Swap		6,000			2,196,000			90.28
											7,867,000
	Product	Settlement				Derivative	Notional			Total			Average
		Period				Instrument	Daily			Notional			Fixed Prices
							Volume			Volume			per Bbl
							(Bbls)			(Bbls)
	NGL-Ethane		2014			Swap		4,500			828,000		$	13.21
	NGL-Propane		2014			Swap		2,785			512,440			44.71
	NGL-Isobutane		2014			Swap		930			171,120			61.26
	NGL-Normal Butane		2014			Swap		875			161,000			60.29
	NGL-Pentanes Plus		2014			Swap		910			167,440			84.97
	NGL-Ethane		2015			Swap		2,500			912,500			11.59
	NGL-Propane		2015			Swap		1,250			456,250			43.26
	NGL-Isobutane		2015			Swap		450			164,250			53.76
	NGL-Normal Butane		2015			Swap		400			146,000			53.76
	NGL-Pentanes Plus		2015			Swap		400			146,000			76.44
											3,665,000
	Product	Settlement				Derivative	Notional			Total			Average			Average
		Period				Instrument	Daily			Notional			Floor/Fixed Prices			Ceiling Prices
							Volume			Volume			per MMBtu			per MMBtu
							(MMBtu)			(MMBtu)
	Natural gas		2014			Costless Collar		50,000			9,200,000			3.6			4.94
	Natural gas		2015			Costless Collar		50,000			18,250,000			3.6			5.04
	Natural gas		2016			Costless Collar		40,000			14,640,000			3.5			5.58
	Natural gas		2014			Swap		30,000			5,520,000			4.07
	Natural gas		2015			Swap		40,000			14,600,000			4.18
	Natural gas		2016			Swap		30,000			10,980,000			4.04
											73,190,000
	As of June 30, 2014, the Company’s derivative instruments were with counterparties who are lenders under its Credit Facility. This practice allows the Company to satisfy any need for margin obligations resulting from an adverse change in the fair market value of its derivative contracts with the collateral securing its Credit Facility, thus eliminating the need for independent collateral postings. The Company’s ability to continue satisfying any applicable margin requirements in this manner may be subject to change as described in Items 1 and 2. Business and Properties – Government Regulation in the Company’s 2013 Annual Report. As of June 30, 2014, the Company had no deposits for collateral regarding commodity derivative positions.
	Discontinuance of Hedge Accounting
	Effective January 1, 2012, the Company elected to de-designate all commodity contracts previously designated as cash flow hedges as of December 31, 2011 and discontinue hedge accounting prospectively. As of December 31, 2013, all frozen mark-to-market values included in Accumulated other comprehensive income were reclassified into earnings. With the election to de-designate hedging instruments, all of the Company’s derivative instruments are recorded at fair value with unrealized gains and losses recognized immediately in earnings rather than in Accumulated other comprehensive income. These mark-to-market adjustments produce a degree of earnings volatility that can be significant from period to period, but such adjustments had no cash flow impact in the current period. The cash flow impact occurs upon settlement of the underlying contract.
	Additional Disclosures about Derivative Instruments
	Authoritative derivative guidance requires companies to recognize all derivative instruments as either assets or liabilities at fair value in the Company’s financial statements. The following table sets forth information on the location and amounts of the Company’s derivative instrument fair values in the Consolidated Balance Sheet as of June 30, 2014 and December 31, 2013, respectively:
				Asset (Liability) Fair Value
				June 30, 2014			December 31, 2013
	Commodity derivative contracts	Location on Consolidated Balance Sheet		(In thousands)
	Oil	Derivative instruments—current assets		$	—		$	1,299
	Oil	Derivative instruments—non-current assets			—			2,117
	Oil	Derivative instruments—current liabilities			(29,703	)		(5,629	)
	Oil	Derivative instruments—non-current liabilities			(18,449	)		—
	NGL	Derivative instruments—current assets			—			2,834
	NGL	Derivative instruments—non-current assets			—			(129	)
	NGL	Derivative instruments—current liabilities			(282	)		461
	NGL	Derivative instruments—non-current liabilities			(1,100	)		(433	)
	Natural gas	Derivative instruments—current assets			—			174
	Natural gas	Derivative instruments—non-current assets			—			3,470
	Natural gas	Derivative instruments—current liabilities			(3,757	)		255
	Natural gas	Derivative instruments—non-current liabilities			(1,819	)		—
	Total derivative fair value, net, not designated as hedging instruments			$	(55,110	)	$	4,419
	The following table sets forth information on the location and amounts of derivative gains and losses in the Consolidated Statement of Operations for the three and six months ended June 30, 2014 and 2013, respectively:
	Location on Consolidated			Three Months Ended						Six Months Ended
	Statement of Operations			June 30,						June 30,
		Description of (Loss) Gain		2014			2013			2014			2013
			(In thousands)
Derivative instruments	(Loss) gain recognized in income			(5,714	)		3,289			(13,651	)		5,291
	Realized (loss) gain recognized in income		$	(5,714	)	$	3,289		$	(13,651	)	$	5,291
Derivative instruments	(Loss) gain recognized in income due to changes in fair value		$	(43,681	)	$	42,763		$	(59,529	)	$	29,217
Derivative instruments	Loss reclassified from Accumulated OCI			—			(2	)		—			(427	)
	Unrealized (loss) gain recognized in income		$	(43,681	)	$	42,761		$	(59,529	)	$	28,790
	Total commodity derivative (loss) gain recognized in income		$	(49,395	)	$	46,050		$	(73,180	)	$	34,081

Fair_Value_Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	(5) Fair Value Measurements
	The Company’s financial assets and liabilities are measured at fair value on a recurring basis. The Company measures its non-financial assets and liabilities, such as asset retirement obligations and other property and equipment, at fair value on a non-recurring basis. See Note 3 – Property and Equipment for more information on the Company’s fair value measurement of non-recurring assets and liabilities related to the 2014 Permian Acquisition.
	As defined in the guidance of the Financial Accounting Standards Board (“FASB”), fair value is the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price). To estimate fair value, the Company utilizes market data and assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable.
	The FASB’s guidance establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted market prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). The three levels of the fair value hierarchy are as follows:
		•		“Level 1” inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities.
		•		“Level 2” inputs are quoted prices for similar assets and liabilities in active markets or inputs that are observable for the asset or liability, either directly or indirectly through market corroboration, for substantially the full term of the financial instrument.
		•		“Level 3” inputs are measured based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable from objective sources.
	As required, financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities along with their placement within the fair value hierarchy levels. The Company determines the appropriate level for each financial asset and liability on a quarterly basis and recognizes any transfers at the end of the reporting period.
	The following table sets forth by level within the fair value hierarchy the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis for the respective period:
			Fair value as of June 30, 2014
			Level 1			Level 2			Level 3			Netting (1)			Total
			(In thousands)
	Assets:
	Money market funds		$	—		$	1,035		$	—		$	—		$	1,035
	Commodity derivative contracts			—			—			8,986			(8,986	)		—
	Liabilities:
	Commodity derivative contracts			—			—			(64,096	)		8,986			(55,110	)
	Total fair value		$	—		$	1,035		$	(55,110	)	$	—		$	(54,075	)
			Fair value as of December 31, 2013
			Level 1			Level 2			Level 3			Netting (1)			Total
			(In thousands)
	Assets:
	Money market funds		$	—		$	1,035		$	—		$	—		$	1,035
	Commodity derivative contracts			—			—			21,675			(11,910	)		9,765
	Liabilities:
	Commodity derivative contracts			—			—			(17,256	)		11,910			(5,346	)
	Total fair value		$	—		$	1,035		$	4,419		$	—		$	5,454
	-1	Represents the impact of netting commodity derivative assets and liabilities with counterparties where the Company has the contractual right and intends to net settle. No margin or collateral balances are deposited with counterparties and as such, gross amounts are offset to determine the net amounts presented in the Consolidated Balance Sheet.
	The Company’s Level 3 instruments include commodity derivative contracts for which fair value is determined by a third-party provider. Although the Company compares the fair values derived from the third-party provider with its counterparties, the Company does not currently have sufficient corroborating market evidence to support classifying these contracts as Level 2 instruments and does not have access to the specific valuation models or certain inputs used by its third-party provider or counterparties. Therefore, these commodity derivative contracts are classified as Level 3 instruments.
	The following table presents a range of the unobservable inputs provided by the Company’s third-party provider utilized in the fair value measurements of the Company’s assets and liabilities classified as Level 3 instruments as of June 30, 2014 (in thousands):
			Asset (Liability)						Range						Weighted
	Level 3 Instrument		(In thousands)			Valuation Technique		Unobservable Input	Minimum			Maximum			Average
	Oil swaps		$	(47,633	)	Discounted cash flow		Forward price curve-swaps	$	90.08		$	105.17		$	96.98
	Oil costless collars			(520	)	Option model		Forward price curve- costless collar option value		(2.30	)		0.34			0.94
	NGL swaps			2,509		Discounted cash flow		Forward price curve-swaps		0.29			1.36			0.59
	NGL swaps			(3,890	)	Discounted cash flow		Forward price curve-swaps		0.28			2.21			0.94
	Natural gas swaps			(4,779	)	Discounted cash flow		Forward price curve-swaps		3.97			4.59			4.27
	Natural gas costless collars			21		Option model		Forward price curve- costless collar option value		(0.22	)		0.16			0
	Natural gas costless collars			(818	)	Option model		Forward price curve- costless collar option value		(0.30	)		0.24			0.03
	Total		$	(55,110	)
	The determination of derivative fair values by the third-party provider incorporates a credit adjustment for nonperformance risk, including the credit standing of the counterparties involved, and the impact of the Company’s nonperformance risk on its liabilities. The Company recorded an upward adjustment to the fair value of its derivative instruments in the amount of $1.3 million as of June 30, 2014.
	The significant unobservable inputs for Level 3 derivative contracts include forward price curves and option values. Significant increases (decreases) in the quoted forward prices for commodities and option values generally lead to corresponding decreases (increases) in the fair value measurement of the Company’s oil, NGL and natural gas derivative contracts.
	The tables below present reconciliations of financial assets and liabilities classified as Level 3 in the fair value hierarchy during the indicated periods.
			Derivative
			Asset (Liability)
			(In thousands)
	Balance at January 1, 2014		$	4,419
	Total Gains or (Losses) (Realized or Unrealized):
	Included in Earnings			(73,180	)
	Purchases, Issuances and Settlements:
	Settlements			13,651
	Transfers in and out of Level 3			—
	Balance at June 30, 2014		$	(55,110	)
			Derivative
			Asset (Liability)
			(In thousands)
	Balance at January 1, 2013		$	20,664
	Total Gains or (Losses) (Realized or Unrealized):
	Included in Earnings			34,508
	Purchases, Issuances and Settlements:
	Settlements			(5,291	)
	Transfers in and out of Level 3			—
	Balance at June 30, 2013		$	49,881
Fair Value of Other Financial Instruments
All of the Company’s other financial instruments (excluding derivatives) are presented on the balance sheet at carrying value. As of June 30, 2014, the carrying value of cash and cash equivalents (excluding money market funds), other current assets and current liabilities reported in the Consolidated Balance Sheet approximate fair value because of their short-term nature, and all such financial instruments are considered Level 1 instruments.
The Company’s debt consists of publicly traded Senior Notes (defined below). The fair values of the Company’s Senior Notes are based upon unadjusted quoted market prices and are considered Level 1 instruments. As of June 30, 2014, the carrying amount of total debt was $1.80 billion and the estimated fair value of total debt was $1.87 billion.

Asset_Retirement_Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligations	'
	(6) Asset Retirement Obligations
	The following table provides a rollforward of the Company’s asset retirement obligations (“ARO”). Liabilities incurred during the period include additions to obligations and obligations incurred from acquisitions. Liabilities settled during the period include settlement payments for obligations. Activity related to the Company’s ARO is as follows:
		Six Months Ended
		June 30, 2014
		(In thousands)
	ARO as of December 31, 2013	$	13,057
	Liabilities incurred during period		2,334
	Liabilities settled during period		—
	Accretion expense		495
	ARO as of June 30, 2014	$	15,886
	As of June 30, 2014, the $4.0 million current portion of the total ARO is included in Accrued liabilities, and the $11.9 million long-term portion of ARO is included in Other long-term liabilities on the Consolidated Balance Sheet.

Debt_and_Credit_Agreements

Debt and Credit Agreements	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Debt and Credit Agreements	'
	(7) Debt and Credit Agreements
	Senior Secured Revolving Credit Facility. On April 2, 2014, the Company entered into the Omnibus Eighth Amendment to Amended and Restated Senior Revolving Credit Agreement (the “Amendment”) with Wells Fargo Bank, National Association, as administrative agent, and the lenders signatory thereto. The Amendment, among other things, (i) authorized the redemption of the Company’s 9.500% Senior Notes due 2018 (the “9.500% Senior Notes”), (ii) increased the borrowing base from $800.0 million to $950.0 million and (iii) reconfirmed the committed amount under the Credit Facility at $800 million with a maximum credit amount of $1.5 billion.
	As of June 30, 2014, the Company had no amounts outstanding with $800.0 million of available borrowing capacity under its Credit Facility. Amounts outstanding under the Credit Facility bear interest at specified margins over the London Interbank Offered Rate (“LIBOR”) of 1.50% to 2.50% and mature in April 2018. Additionally, the Company can borrow under the Credit Facility at the Alternative Base Rate (“ABR”), which is based upon the Prime Rate in effect on such day plus a margin of 0.5% to 1.5% depending on the Company’s utilization percentage. The weighted average borrowing rate under the Credit Facility for the three and six months ended June 30, 2014 was 2.65% and 2.38%, respectively, exclusive of commitment fees. For the three and six months ended June 30, 2014, interest expense was $0.9 million and $1.0 million, respectively, and commitment fees were $0.6 million and $1.4 million, respectively, under the Credit Facility. Borrowings under the Credit Facility are collateralized by liens and security interests on substantially all of the Company’s assets, including a mortgage lien on oil and natural gas properties having at least 80% of the pre-tax SEC PV-10 proved reserve value, a guaranty by all of the Company’s domestic subsidiaries and a pledge of 100% of the membership and limited partnership interests of the Company’s domestic subsidiaries. Collateralized amounts under the mortgages are subject to semi-annual reviews based on updated reserve information. The Company is also subject to certain financial covenants, including the requirement to maintain a minimum current ratio of consolidated current assets, including the unused amount of available borrowing capacity, to consolidated current liabilities, excluding certain non-cash obligations, of not less than 1.0 to 1.0 as of the end of each fiscal quarter. The terms of the credit agreement also require the maintenance of a maximum leverage ratio of total debt to earnings before interest expense, income taxes and noncash items, such as depreciation, depletion, amortization and impairment, of not greater than 4.0 to 1.0, calculated at the end of each fiscal quarter for the four fiscal quarters then ended, measured quarterly after giving pro forma effect to acquisitions and divestitures. As of June 30, 2014, the Company’s current ratio was 2.9 and leverage ratio was 2.8. In addition, the Company is subject to covenants limiting dividends and other restricted payments, transactions with affiliates, incurrence of debt, changes of control, asset sales and liens on properties.
	9.500% Senior Notes due 2018. In accordance with the provisions of the indenture governing the Company’s 9.500% Senior Notes, on May 5, 2014, the Company redeemed all of the outstanding notes in full at a price of 104.75% of the principal amount, plus accrued and unpaid interest. The Company paid an aggregate amount of $210.6 million for such redemption, consisting of a call premium of $9.5 million and $1.1 million of accrued and unpaid interest. The call premium of $9.5 million and remaining unamortized debt issuance costs of $3.1 million are included in Other expense in the Company’s Consolidated Statement of Operations in the second quarter of 2014.
	5.625% Senior Notes due 2021. On May 2, 2013, the Company completed its public offering of $700.0 million in aggregate principal amount of 5.625% Senior Notes due 2021 (the “5.625% Senior Notes”). Interest is payable on the 5.625% Senior Notes semi-annually on May 1 and November 1. The 5.625% Senior Notes were issued under an indenture (the “Base Indenture”), as supplemented by a first supplemental indenture (as so supplemented, the “5.625% Senior Notes Indenture”) with Wells Fargo Bank, National Association, as trustee. Provisions of the 5.625% Senior Notes Indenture limit the Company’s ability to, among other things, incur additional indebtedness; pay dividends on capital stock or purchase, repurchase, redeem, defease or retire capital stock or subordinated indebtedness; make investments; incur liens; create any consensual restriction on the ability of the Company’s restricted subsidiaries to pay dividends, make loans or transfer property to the Company; engage in transactions with affiliates; sell assets; and consolidate, merge or transfer assets. The 5.625% Senior Notes Indenture also contains customary events of default.
	5.875% Senior Notes due 2022. On November 15, 2013, the Company completed its public offering of $600.0 million in aggregate principal amount of 5.875% Senior Notes due 2022 (the “5.875% Senior Notes due 2022”). Interest is payable on the 5.875% Senior Notes due 2022 semi-annually on June 1 and December 1. The 5.875% Senior Notes due 2022 were issued under the Base Indenture, as supplemented by a second supplemental indenture with Wells Fargo Bank, National Association, as trustee, which contains covenants and events of default substantially similar to those in the 5.625% Senior Notes Indenture.
	5.875% Senior Notes due 2024. On May 29, 2014, the Company completed its public offering of $500.0 million in aggregate principal amount of 5.875% Senior Notes due 2024 (the “5.875% Senior Notes due 2024” and, together with the 5.625% Senior Notes and the 5.875% Senior Notes due 2022, the “Senior Notes”). Interest is payable on the 5.875% Senior Notes due 2024 semi-annually on June 1 and December 1. The 5.875% Senior Notes due 2024 were issued under the Base Indenture, as supplemented by a third supplemental indenture with Wells Fargo Bank, National Association, as trustee, which contains covenants and events of default substantially similar to those in the 5.625% Senior Notes Indenture.
	Total Indebtedness. As of June 30, 2014, the Company had total outstanding borrowings of $1.80 billion, and for the six months ended June 30, 2014, the Company’s weighted average borrowing rate was 6.04%, inclusive of interest and commitment fees.

Income_Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2014
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	(8) Income Taxes
	The Company’s effective tax rate for the three and six months ended June 30, 2014 was 36.7% and 35.7%, respectively, and the effective tax rate for the three and six months ended June 30, 2013 was 36.2% and 35.1%, respectively. The provision for income taxes for the three and six months ended June 30, 2014 differs from the tax computed at the federal statutory income tax rate primarily due to the impact of state income taxes and the non-deductibility of certain incentive compensation. As of June 30, 2014 and December 31, 2013, the Company had no unrecognized tax benefits. The Company does not anticipate that total unrecognized tax benefits will significantly change due to the settlement of audits or the expiration of statutes of limitation within the next twelve months.
	The Company provides for deferred income taxes on the difference between the tax basis of an asset or liability and its carrying amount in the financial statements in accordance with authoritative guidance for accounting for income taxes. This difference will result in taxable income or deductions in future years when the reported amount of the asset or liability is recovered or settled, respectively. Considerable judgment is required in determining when these events may occur and whether recovery of an asset is more likely than not. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. As of June 30, 2014, the Company had a net deferred tax liability of $135.0 million resulting primarily from the differences between the book basis and tax basis of the Company’s oil and natural gas properties, partially offset by net operating loss carryforwards.

Commitments_and_Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments And Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	(9) Commitments and Contingencies
	Firm Oil and Natural Gas Transportation and Processing Commitments. The Company has commitments for the transportation and processing of its production in the Eagle Ford area and has an aggregate minimum commitment to deliver 5.3 MMBbls of oil by the end of 2017 and 612 million MMBtus of natural gas by mid-year 2028. The Company is required to make periodic deficiency payments for any shortfalls in delivering the minimum volumes under these commitments. Currently, the Company has insufficient production to meet all of these contractual commitments. As the Company develops additional reserves in the Eagle Ford area, it anticipates exceeding its current minimum volume commitments and therefore intends to enter into additional transportation and processing commitments in the future. These future transportation and processing commitments could expose the Company to additional volume deficiency payments. As of June 30, 2014, the Company has accrued deficiency fees of $4.1 million and expects to continue to accrue deficiency fees under its commitments. Future obligations under firm oil and natural gas transportation and processing agreements as of June 30, 2014 are as follows:
		June 30, 2014
		(In thousands)
	2014	$	10,352
	2015		22,818
	2016		22,132
	2017		21,708
	2018		18,159
	Thereafter		102,406
	Total future obligations	$	197,575
	Drilling Rig and Completion Services Commitments. Drilling rig and completion services commitments represent obligations with certain contractors to execute the Company’s Eagle Ford and Permian Basin drilling programs. As of June 30, 2014, the Company had three outstanding drilling rig commitments with terms greater than one year that will expire by the end of 2016, and the minimum contractual commitments due in the next twelve months were $21.8 million. Payments under these commitments are accounted for as capital additions to oil and gas properties. As of June 30, 2014, the Company’s minimum contractual commitments due in the next twelve months for completion services agreements for the stimulation, cementing and delivery of drilling fluids and other field service commitments were $9.4 million. Payments under these commitments are accounted for as capital additions to oil and gas properties or as Lease operating expense, depending on the nature of the related expenditures.
	Contingencies. The Company is party to various legal and regulatory proceedings and commercial disputes arising in the normal course of business. The ultimate outcome of each of these matters cannot be absolutely determined, and in the event of a negative outcome as to any proceeding, the liability the Company may ultimately incur with respect to any such proceeding may be in excess of amounts currently accrued, if any. After considering the Company’s available insurance and, to the extent applicable, that of third parties, and the performance of contractual defense and indemnity rights and obligations, where applicable, the Company does not believe any such matter will have a material adverse effect on its financial position, results of operations or cash flows.

Equity

Equity	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Equity	'
	(10) Equity
	Earnings per Share. Basic earnings per share (“EPS”) is calculated by dividing net income (the numerator) by the weighted-average number of shares of common stock (excluding unvested restricted stock awards) outstanding during the period (the denominator). Diluted EPS incorporates the dilutive impact of outstanding stock options and unvested restricted stock awards using the treasury stock method.
	The following is a calculation of basic and diluted weighted average shares outstanding:
		Three Months Ended June 30,				Six Months Ended June 30,
		2014		2013		2014		2013
		(In thousands)
	Basic weighted average number of shares outstanding		61,452		58,990		61,416		55,879
	Dilution effect of stock option and restricted shares at the end of the period		165		211		183		286
	Diluted weighted average number of shares outstanding		61,617		59,201		61,599		56,165
	Anti-dilutive stock awards and shares		—		6		5		2
	Common Stock Offering. On April 23, 2013, the Company completed its public offering of 7,000,000 shares of common stock at a price to the public of $42.50 per share for net proceeds of approximately $286.3 million ($40.80 per share, net of underwriting discounts and commissions), including offering expenses and reimbursements by the underwriters of certain expenses incurred in connection with the offering. The Company also received net proceeds of approximately $43.0 million in connection with the underwriters’ full exercise of their over-allotment option to purchase 1,050,000 additional shares of common stock, which closed on April 29, 2013.

StockBased_Compensation_and_Em

Stock-Based Compensation and Employee Benefits	6 Months Ended
	Jun. 30, 2014
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]	'
Stock-Based Compensation and Employee Benefits	'
	(11) Stock-Based Compensation and Employee Benefits
	Stock-based compensation expense includes the expense associated with restricted stock granted to employees and directors and the expense associated with the Performance Share Units (“PSUs”) granted to management. As of the indicated dates, stock-based compensation expense consisted of the following:
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
		(In thousands)
	Total stock-based compensation expense	$	4,158		$	2,303		$	7,639		$	5,041
	Capitalized in oil and gas properties		(123	)		(74	)		(246	)		(148	)
	Net stock-based compensation expense	$	4,035		$	2,229		$	7,393		$	4,893
	All stock-based compensation expense associated with restricted stock granted to employees and directors is recognized on a straight-line basis over the applicable remaining vesting period. For the three and six months ended June 30, 2014, the Company recorded compensation expense of approximately $2.3 million and $5.0 million, respectively, related to these equity awards. As of June 30, 2014, unrecognized stock-based compensation expense related to unvested restricted stock was approximately $15.9 million.
	Stock-based compensation expense associated with the PSUs granted to management is recognized over a three-year performance period. For the three and six months ended June 30, 2014, the Company recognized compensation expense of $1.8 million and $2.6 million, respectively, associated with the PSUs. At the current fair value as of June 30, 2014, and assuming the Board elects the maximum available payout of 200% for all PSU metrics, unrecognized stock-based compensation expense related to the PSUs was approximately $20.2 million. The Company’s total stock-based compensation expense will be measured and adjusted quarterly until settlement occurs, based on the Company’s performance, expected payout and quarter-end closing common stock prices. For a more detailed description of the Company’s PSU plans, including related performance conditions and structure, see the definitive proxy statement filed with respect to the Company’s 2014 annual meeting under the heading “Compensation Discussion and Analysis” and the Company’s 2013 Annual Report.
	Postretirement Health Care. Effective January 1, 2013, the Company enacted a postretirement medical benefit plan covering eligible employees and their eligible dependents. Upon enactment, the Company recognized a $0.3 million liability related to the prior service of employees which is included as a component of Other comprehensive income. The Company recognizes periodic postretirement benefits cost as a component of General and administrative costs. For both the three and six months ended June 30, 2014, this expense was immaterial.

Guarantor_Subsidiaries

Guarantor Subsidiaries	6 Months Ended
	Jun. 30, 2014
Guarantees [Abstract]	'
Guarantor Subsidiaries	'
	(12) Guarantor Subsidiaries
	The Company’s Senior Notes are guaranteed by its wholly owned subsidiaries. Rosetta Resources Inc., as the parent company, has no independent assets or operations. The guarantees are full and unconditional and joint and several. In addition, there are no restrictions on the ability of the Company to obtain funds from its subsidiaries by dividend or loan. Finally, none of the Company’s subsidiaries has restricted assets that exceed 25% of net assets as of the most recent fiscal year which may not be transferred to the Company in the form of loans, advances or cash dividends by the subsidiaries without the consent of a third party.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Recent Accounting Developments	'
	Recent Accounting Developments
	In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers. The ASU will supersede most of the existing revenue recognition requirements in GAAP and will require entities to recognize revenue at an amount that reflects the consideration to which the Company expects to be entitled in exchange for transferring goods or services to a customer. The new standard also requires disclosures sufficient to enable users to understand an entity’s nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The pronouncement is effective for annual and interim reporting periods beginning after December 15, 2016, and is to be applied retrospectively, with early application not permitted. This guidance is not expected to have a material impact on the Company’s consolidated financial position, results of operations, or cash flows.

Property_and_Equipment_Tables

Property and Equipment (Tables)	6 Months Ended
	Jun. 30, 2014
Extractive Industries [Abstract]	'
Schedule of Total Property, Plant and Equipment, Net	'
	The Company’s Total property and equipment, net consists of the following:
			June 30, 2014			December 31, 2013
			(In thousands)
	Proved properties		$	4,937,235		$	3,951,397
	Unproved/unevaluated properties			511,762			755,438
	Gathering systems and compressor stations			262,424			168,730
	Other fixed assets			28,316			26,362
	Total			5,739,737			4,901,927
	Less: Accumulated depreciation, depletion and amortization			(2,185,100	)		(2,020,879	)
	Total property and equipment, net		$	3,554,637		$	2,881,048
Schedule of Consideration Paid Assets Acquired and Liabilities Assumed	'
	The final purchase price allocation for the 2013 Permian and Gates Ranch Acquisitions and the preliminary purchase price allocation for the 2014 Permian Acquisition, representing consideration paid, assets acquired and liabilities assumed as of the respective acquisition dates, are shown in the tables below.
	2014 Permian Acquisition
			Preliminary Total Purchase
			Price Allocation
			(In thousands)
	Cash consideration		$	83,172
	Fair value of assets acquired:
	Oil and natural gas properties
	Proved properties		$	61,598
	Unproved/unevaluated properties			21,867
	Total assets acquired		$	83,465
	Fair value of liabilities assumed:
	Asset retirement obligations		$	293
	Net assets acquired		$	83,172
	2013 Permian Acquisition and Gates Ranch Acquisition
			Final Total Purchase
			Price Allocation
			(In thousands)
	Cash consideration		$	953,242
	Fair value of assets acquired:
	Other fixed assets		$	600
	Oil and natural gas properties
	Proved properties			290,273
	Unproved/unevaluated properties			663,300
	Total assets acquired		$	954,173
	Fair value of liabilities assumed:
	Asset retirement obligations		$	931
	Net assets acquired		$	953,242
Schedule of Results of Operations at the Time of Transactions	'
	The pro forma results of operations do not include any cost savings or other synergies that may result from the acquisitions, or any estimated costs that have been or will be incurred by the Company to integrate these assets. The pro forma information does not purport to represent what the Company’s results of operations would have been if the 2013 Permian Acquisition and Gates Acquisition had occurred on January 1, 2012 and the 2014 Permian Acquisition had occurred on January 1, 2013.
			Three Months Ended June 30,						Six Months Ended June 30,
			2014 (1)			2013			2014 (2)		2013
			(In thousands, except per share and share data)						(In thousands, except per share and share data)
	Total revenues		$	220,890		$	254,986		$	438,553	$	457,901
	Net income			14,444			73,625			50,480		126,350
	Earnings per share:
	Basic		$	0.24		$	1.21		$	0.82	$	2.07
	Diluted		$	0.23		$	1.2		$	0.82	$	2.06
	Weighted average shares outstanding:
	Basic			61,452			61,094			61,416		60,939
	Diluted			61,617			61,305			61,599		61,226
	-1	No pro forma adjustments were made for the period as all acquisitions and related financings are included in the Company’s historical results.
	-2	No pro forma adjustments were made related to the 2013 Permian Acquisition and Gates Acquisition for the period as the acquisitions are included in the Company’s historical results.

Commodity_Derivative_Contracts1

Commodity Derivative Contracts (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments And Hedging Activities Disclosure [Abstract]	'
Schedule of Derivative Instruments	'
	As of June 30, 2014, the following derivative contracts were outstanding with associated notional volumes and average underlying prices that represent hedged prices of commodities at various market locations:
	Product	Settlement				Derivative	Notional			Total			Average			Average
		Period				Instrument	Daily			Notional			Floor/Fixed Prices			Ceiling Prices
							Volume			Volume			per Bbl			per Bbl
							(Bbls)			(Bbls)
	Crude oil		2014			Costless Collar		3,000			552,000		$	83.33		$	109.63
	Crude oil		2014			Swap		6,000			1,104,000			93.13
	Crude oil		2015			Swap		11,000			4,015,000			89.51
	Crude oil		2016			Swap		6,000			2,196,000			90.28
											7,867,000
	Product	Settlement				Derivative	Notional			Total			Average
		Period				Instrument	Daily			Notional			Fixed Prices
							Volume			Volume			per Bbl
							(Bbls)			(Bbls)
	NGL-Ethane		2014			Swap		4,500			828,000		$	13.21
	NGL-Propane		2014			Swap		2,785			512,440			44.71
	NGL-Isobutane		2014			Swap		930			171,120			61.26
	NGL-Normal Butane		2014			Swap		875			161,000			60.29
	NGL-Pentanes Plus		2014			Swap		910			167,440			84.97
	NGL-Ethane		2015			Swap		2,500			912,500			11.59
	NGL-Propane		2015			Swap		1,250			456,250			43.26
	NGL-Isobutane		2015			Swap		450			164,250			53.76
	NGL-Normal Butane		2015			Swap		400			146,000			53.76
	NGL-Pentanes Plus		2015			Swap		400			146,000			76.44
											3,665,000
	Product	Settlement				Derivative	Notional			Total			Average			Average
		Period				Instrument	Daily			Notional			Floor/Fixed Prices			Ceiling Prices
							Volume			Volume			per MMBtu			per MMBtu
							(MMBtu)			(MMBtu)
	Natural gas		2014			Costless Collar		50,000			9,200,000			3.6			4.94
	Natural gas		2015			Costless Collar		50,000			18,250,000			3.6			5.04
	Natural gas		2016			Costless Collar		40,000			14,640,000			3.5			5.58
	Natural gas		2014			Swap		30,000			5,520,000			4.07
	Natural gas		2015			Swap		40,000			14,600,000			4.18
	Natural gas		2016			Swap		30,000			10,980,000			4.04
											73,190,000
Schedule of Derivative Instruments in Statement of Financial Position	'
	he following table sets forth information on the location and amounts of the Company’s derivative instrument fair values in the Consolidated Balance Sheet as of June 30, 2014 and December 31, 2013, respectively:
				Asset (Liability) Fair Value
				June 30, 2014			December 31, 2013
	Commodity derivative contracts	Location on Consolidated Balance Sheet		(In thousands)
	Oil	Derivative instruments—current assets		$	—		$	1,299
	Oil	Derivative instruments—non-current assets			—			2,117
	Oil	Derivative instruments—current liabilities			(29,703	)		(5,629	)
	Oil	Derivative instruments—non-current liabilities			(18,449	)		—
	NGL	Derivative instruments—current assets			—			2,834
	NGL	Derivative instruments—non-current assets			—			(129	)
	NGL	Derivative instruments—current liabilities			(282	)		461
	NGL	Derivative instruments—non-current liabilities			(1,100	)		(433	)
	Natural gas	Derivative instruments—current assets			—			174
	Natural gas	Derivative instruments—non-current assets			—			3,470
	Natural gas	Derivative instruments—current liabilities			(3,757	)		255
	Natural gas	Derivative instruments—non-current liabilities			(1,819	)		—
	Total derivative fair value, net, not designated as hedging instruments			$	(55,110	)	$	4,419
Schedule of Derivative Gains and Losses in Consolidated Statement of Operations	'
	The following table sets forth information on the location and amounts of derivative gains and losses in the Consolidated Statement of Operations for the three and six months ended June 30, 2014 and 2013, respectively:
	Location on Consolidated			Three Months Ended						Six Months Ended
	Statement of Operations			June 30,						June 30,
		Description of (Loss) Gain		2014			2013			2014			2013
				(In thousands)
	Derivative instruments	(Loss) gain recognized in income			(5,714	)		3,289			(13,651	)		5,291
		Realized (loss) gain recognized in income		$	(5,714	)	$	3,289		$	(13,651	)	$	5,291
	Derivative instruments	(Loss) gain recognized in income due to changes in fair value		$	(43,681	)	$	42,763		$	(59,529	)	$	29,217
	Derivative instruments	Loss reclassified from Accumulated OCI			—			(2	)		—			(427	)
		Unrealized (loss) gain recognized in income		$	(43,681	)	$	42,761		$	(59,529	)	$	28,790
		Total commodity derivative (loss) gain recognized in income		$	(49,395	)	$	46,050		$	(73,180	)	$	34,081

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Schedule of Fair Value Assets and Liabilities Measured on Recurring Basis	'
	The following table sets forth by level within the fair value hierarchy the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis for the respective period:
			Fair value as of June 30, 2014
			Level 1			Level 2			Level 3			Netting (1)			Total
			(In thousands)
	Assets:
	Money market funds		$	—		$	1,035		$	—		$	—		$	1,035
	Commodity derivative contracts			—			—			8,986			(8,986	)		—
	Liabilities:
	Commodity derivative contracts			—			—			(64,096	)		8,986			(55,110	)
	Total fair value		$	—		$	1,035		$	(55,110	)	$	—		$	(54,075	)
			Fair value as of December 31, 2013
			Level 1			Level 2			Level 3			Netting (1)			Total
			(In thousands)
	Assets:
	Money market funds		$	—		$	1,035		$	—		$	—		$	1,035
	Commodity derivative contracts			—			—			21,675			(11,910	)		9,765
	Liabilities:
	Commodity derivative contracts			—			—			(17,256	)		11,910			(5,346	)
	Total fair value		$	—		$	1,035		$	4,419		$	—		$	5,454
	-1	Represents the impact of netting commodity derivative assets and liabilities with counterparties where the Company has the contractual right and intends to net settle. No margin or collateral balances are deposited with counterparties and as such, gross amounts are offset to determine the net amounts presented in the Consolidated Balance Sheet.
Schedule of Valuation Process and Unobservable Inputs	'
	The following table presents a range of the unobservable inputs provided by the Company’s third-party provider utilized in the fair value measurements of the Company’s assets and liabilities classified as Level 3 instruments as of June 30, 2014 (in thousands):
			Asset (Liability)						Range						Weighted
	Level 3 Instrument		(In thousands)			Valuation Technique		Unobservable Input	Minimum			Maximum			Average
	Oil swaps		$	(47,633	)	Discounted cash flow		Forward price curve-swaps	$	90.08		$	105.17		$	96.98
	Oil costless collars			(520	)	Option model		Forward price curve- costless collar option value		(2.30	)		0.34			0.94
	NGL swaps			2,509		Discounted cash flow		Forward price curve-swaps		0.29			1.36			0.59
	NGL swaps			(3,890	)	Discounted cash flow		Forward price curve-swaps		0.28			2.21			0.94
	Natural gas swaps			(4,779	)	Discounted cash flow		Forward price curve-swaps		3.97			4.59			4.27
	Natural gas costless collars			21		Option model		Forward price curve- costless collar option value		(0.22	)		0.16			0
	Natural gas costless collars			(818	)	Option model		Forward price curve- costless collar option value		(0.30	)		0.24			0.03
	Total		$	(55,110	)
Schedule of Fair Value Assets and Liabilities Classified	'
	The tables below present reconciliations of financial assets and liabilities classified as Level 3 in the fair value hierarchy during the indicated periods.
			Derivative
			Asset (Liability)
			(In thousands)
	Balance at January 1, 2014		$	4,419
	Total Gains or (Losses) (Realized or Unrealized):
	Included in Earnings			(73,180	)
	Purchases, Issuances and Settlements:
	Settlements			13,651
	Transfers in and out of Level 3			—
	Balance at June 30, 2014		$	(55,110	)
			Derivative
			Asset (Liability)
			(In thousands)
	Balance at January 1, 2013		$	20,664
	Total Gains or (Losses) (Realized or Unrealized):
	Included in Earnings			34,508
	Purchases, Issuances and Settlements:
	Settlements			(5,291	)
	Transfers in and out of Level 3			—
	Balance at June 30, 2013		$	49,881

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Schedule of Asset Retirement Obligations	'
	Activity related to the Company’s ARO is as follows:
		Six Months Ended
		June 30, 2014
		(In thousands)
	ARO as of December 31, 2013	$	13,057
	Liabilities incurred during period		2,334
	Liabilities settled during period		—
	Accretion expense		495
	ARO as of June 30, 2014	$	15,886

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	6 Months Ended
	Jun. 30, 2014
Commitments And Contingencies Disclosure [Abstract]	'
Future Obligations Under Firm Gas and Oil Transportation Agreements	'
	Future obligations under firm oil and natural gas transportation and processing agreements as of June 30, 2014 are as follows:
		June 30, 2014
		(In thousands)
	2014	$	10,352
	2015		22,818
	2016		22,132
	2017		21,708
	2018		18,159
	Thereafter		102,406
	Total future obligations	$	197,575

Equity_Tables

Equity (Tables)	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Schedule of Basic and Diluted Weighted Average Shares Outstanding	'
	The following is a calculation of basic and diluted weighted average shares outstanding:
		Three Months Ended June 30,				Six Months Ended June 30,
		2014		2013		2014		2013
		(In thousands)
	Basic weighted average number of shares outstanding		61,452		58,990		61,416		55,879
	Dilution effect of stock option and restricted shares at the end of the period		165		211		183		286
	Diluted weighted average number of shares outstanding		61,617		59,201		61,599		56,165
	Anti-dilutive stock awards and shares		—		6		5		2

StockBased_Compensation_and_Em1

Stock-Based Compensation and Employee Benefits (Tables)	6 Months Ended
	Jun. 30, 2014
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]	'
Schedule of Stock-Based Compensation Expense	'
	As of the indicated dates, stock-based compensation expense consisted of the following:
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
		(In thousands)
	Total stock-based compensation expense	$	4,158		$	2,303		$	7,639		$	5,041
	Capitalized in oil and gas properties		(123	)		(74	)		(246	)		(148	)
	Net stock-based compensation expense	$	4,035		$	2,229		$	7,393		$	4,893

Property_and_Equipment_Schedul

Property and Equipment - Schedule of Total Property, Plant and Equipment, Net (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Capitalized Costs, Oil and Gas Producing Activities, Net [Abstract]	'	'
Proved properties	$4,937,235	$3,951,397
Unproved/unevaluated properties	511,762	755,438
Gathering systems and compressor stations	262,424	168,730
Other fixed assets	28,316	26,362
Total	5,739,737	4,901,927
Less: Accumulated depreciation, depletion and amortization	-2,185,100	-2,020,879
Total property and equipment, net	$3,554,637	$2,881,048

Property_and_Equipment_Additio

Property and Equipment - Additional Information (Detail) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Transaction cost	$31	'	$31	'	'
Equity issuance costs and related expenses	'	'	13.1	'	'
Acquisition related fees, included in general and administrative costs	'	'	2.3	'	'
Capitalized internal cost	2.1	1.8	3.7	3.9	'
Oil and natural gas properties excluded from amortization, full cost method	'	'	511.8	'	755.4
Impairment charges related to of unproved properties and unevaluated exploration projects transferred to full cost pool	'	'	147.9	'	'
Bridge Loan [Member]	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Commitment fees and related expenses	'	'	5.6	'	'
Senior Notes [Member]	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Debt issuance costs	'	'	10	'	'
Senior notes, percentage	5.63%	'	5.63%	'	'
Adjusted For Basis And Quality Differentials [Member]	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
West Texas Intermediate oil price (per Bbl)	96.75	'	96.75	'	'
Henry Hub natural gas price (per MMBtu)	4.1	'	4.1	'	'
Delaware Basin [Member]	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Area of land acquired	'	'	'	'	5,034
Number of wells acquired	'	'	'	'	13
Number of operating wells	'	'	'	'	11
Payments to acquire businesses	'	'	'	'	83.2
Acquisition date	'	'	'	'	28-Feb-14
Acquisition effective date	'	'	'	'	1-Dec-13
2014 Permian Acquisition [Member]	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Increase in total revenue	4.4	'	5.9	'	'
Increase in operating income	1.7	'	2.3	'	'
Eagle Ford Shale [Member]	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Acquisition date	'	'	5-Jun-13	'	'
Percentage of working interests acquired	10.00%	'	10.00%	'	'
Working interest acquisition, total consideration	'	'	128.1	'	'
Eagle Ford Shale [Member] | South Texas Gates Ranch [Member]	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Percentage of working interests acquired	100.00%	'	100.00%	'	'
Texas [Member]	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Payments to acquire businesses	'	'	$825.20	'	'
Acquisition effective date	'	'	1-Jan-13	'	'
Acquisition date	'	'	14-May-13	'	'

Property_and_Equipment_Schedul1

Property and Equipment - Schedule of Consideration Paid Asset Acquired and Liabilities Assumed (Detail) (Level 3 [Member], USD $)	Jun. 30, 2014
In Thousands, unless otherwise specified
2014 Permian Acquisition [Member]	'
Property, Plant and Equipment [Line Items]	'
Cash consideration	$83,172
Oil and natural gas properties	'
Proved properties	61,598
Unproved/unevaluated properties	21,867
Total assets acquired	83,465
Fair value of liabilities assumed:	'
Asset retirement obligations	293
Net assets acquired	83,172
2013 Permian Acquisition and Gates Ranch Acquisition [Member]	'
Property, Plant and Equipment [Line Items]	'
Cash consideration	953,242
Fair value of assets acquired:	'
Other fixed assets	600
Oil and natural gas properties	'
Proved properties	290,273
Unproved/unevaluated properties	663,300
Total assets acquired	954,173
Fair value of liabilities assumed:	'
Asset retirement obligations	931
Net assets acquired	$953,242

Property_and_Equipment_Schedul2

Property and Equipment - Schedule of Results of Operations at the Time of Transactions (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Property Plant And Equipment Useful Life And Values [Abstract]	'	'	'	'
Total revenues	$220,890	$254,986	$438,553	$457,901
Net income	$14,444	$73,625	$50,480	$126,350
Earnings per share:	'	'	'	'
Basic	$0.24	$1.21	$0.82	$2.07
Diluted	$0.23	$1.20	$0.82	$2.06
Weighted average shares outstanding:	'	'	'	'
Basic	61,452	61,094	61,416	60,939
Diluted	61,617	61,305	61,599	61,226

Commodity_Derivative_Contracts2

Commodity Derivative Contracts - Schedule of Derivative Instruments (Detail)	Jun. 30, 2014
	MMBTU
Natural Gas [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Total Notional Volume MMBtu	73,190,000
NGL-Product [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Total Notional Volume	3,665,000
Crude Oil [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Total Notional Volume	7,867,000
Costless Collar [Member] | 2014 Settlement Period [Member] | Natural Gas [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume MMBtu	50,000
Total Notional Volume MMBtu	9,200,000
Average Fixed Prices per Bbl	3.6
Average Ceiling Prices per Bbl	4.94
Costless Collar [Member] | 2014 Settlement Period [Member] | Crude Oil [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	3,000
Total Notional Volume	552,000
Average Fixed Prices per Bbl	83.33
Average Ceiling Prices per Bbl	109.63
Costless Collar [Member] | 2015 Settlement Period [Member] | Natural Gas [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume MMBtu	50,000
Total Notional Volume MMBtu	18,250,000
Average Fixed Prices per Bbl	3.6
Average Ceiling Prices per Bbl	5.04
Costless Collar [Member] | 2016 Settlement Period [Member] | Natural Gas [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume MMBtu	40,000
Total Notional Volume MMBtu	14,640,000
Average Fixed Prices per Bbl	3.5
Average Ceiling Prices per Bbl	5.58
Swap [Member] | 2014 Settlement Period [Member] | Natural Gas [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume MMBtu	30,000
Total Notional Volume MMBtu	5,520,000
Average Fixed Prices per Bbl	4.07
Swap [Member] | 2014 Settlement Period [Member] | NGL-Ethane [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	4,500
Total Notional Volume	828,000
Average Fixed Prices per Bbl	13.21
Swap [Member] | 2014 Settlement Period [Member] | NGL-Propane [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	2,785
Total Notional Volume	512,440
Average Fixed Prices per Bbl	44.71
Swap [Member] | 2014 Settlement Period [Member] | NGL-Isobutane [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	930
Total Notional Volume	171,120
Average Fixed Prices per Bbl	61.26
Swap [Member] | 2014 Settlement Period [Member] | NGL-Normal Butane [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	875
Total Notional Volume	161,000
Average Fixed Prices per Bbl	60.29
Swap [Member] | 2014 Settlement Period [Member] | NGL-Pentanes Plus [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	910
Total Notional Volume	167,440
Average Fixed Prices per Bbl	84.97
Swap [Member] | 2014 Settlement Period [Member] | Crude Oil [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	6,000
Total Notional Volume	1,104,000
Average Fixed Prices per Bbl	93.13
Swap [Member] | 2015 Settlement Period [Member] | Natural Gas [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume MMBtu	40,000
Total Notional Volume MMBtu	14,600,000
Average Fixed Prices per Bbl	4.18
Swap [Member] | 2015 Settlement Period [Member] | NGL-Ethane [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	2,500
Total Notional Volume	912,500
Average Fixed Prices per Bbl	11.59
Swap [Member] | 2015 Settlement Period [Member] | NGL-Propane [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	1,250
Total Notional Volume	456,250
Average Fixed Prices per Bbl	43.26
Swap [Member] | 2015 Settlement Period [Member] | NGL-Isobutane [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	450
Total Notional Volume	164,250
Average Fixed Prices per Bbl	53.76
Swap [Member] | 2015 Settlement Period [Member] | NGL-Normal Butane [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	400
Total Notional Volume	146,000
Average Fixed Prices per Bbl	53.76
Swap [Member] | 2015 Settlement Period [Member] | NGL-Pentanes Plus [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	400
Total Notional Volume	146,000
Average Fixed Prices per Bbl	76.44
Swap [Member] | 2015 Settlement Period [Member] | Crude Oil [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	11,000
Total Notional Volume	4,015,000
Average Fixed Prices per Bbl	89.51
Swap [Member] | 2016 Settlement Period [Member] | Natural Gas [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume MMBtu	30,000
Total Notional Volume MMBtu	10,980,000
Average Fixed Prices per Bbl	4.04
Swap [Member] | 2016 Settlement Period [Member] | Crude Oil [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Notional Daily Volume	6,000
Total Notional Volume	2,196,000
Average Fixed Prices per Bbl	90.28

Commodity_Derivative_Contracts3

Commodity Derivative Contracts - Schedule of Derivative Instruments in Statement of Financial Position (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	($55,110)	'
Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	-55,110	4,419
Commodity Contracts [Member] | Current Assets [Member] | Crude Oil [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	0	1,299
Commodity Contracts [Member] | Current Assets [Member] | NGL [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	0	2,834
Commodity Contracts [Member] | Current Assets [Member] | Natural Gas [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	0	174
Commodity Contracts [Member] | Non-Current Assets [Member] | Crude Oil [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	0	2,117
Commodity Contracts [Member] | Non-Current Assets [Member] | NGL [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	0	-129
Commodity Contracts [Member] | Non-Current Assets [Member] | Natural Gas [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	0	3,470
Commodity Contracts [Member] | Current Liabilities [Member] | Crude Oil [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	-29,703	-5,629
Commodity Contracts [Member] | Current Liabilities [Member] | NGL [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	-282	461
Commodity Contracts [Member] | Current Liabilities [Member] | Natural Gas [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	-3,757	255
Commodity Contracts [Member] | Noncurrent Liabilities [Member] | Crude Oil [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	-18,449	'
Commodity Contracts [Member] | Noncurrent Liabilities [Member] | NGL [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	-1,100	-433
Commodity Contracts [Member] | Noncurrent Liabilities [Member] | Natural Gas [Member] | Derivatives Not Designated As Hedging Instruments [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative instruments	($1,819)	'

Commodity_Derivative_Contracts4

Commodity Derivative Contracts - Schedule of Derivative Gains and Losses in Consolidated Statement of Operations (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Realized (loss) gain recognized in income	($5,714)	$3,289	($13,651)	$5,291
Unrealized (loss) gain recognized in income	-43,681	42,761	-59,529	28,790
Total commodity derivative (loss) gain recognized in income	-49,395	46,050	-73,180	34,081
Derivative Instruments [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
(Loss) gain recognized in income	-5,714	3,289	-13,651	5,291
(Loss) gain recognized in income due to changes in fair value	-43,681	42,763	-59,529	29,217
Loss reclassified from Accumulated OCI	$0	($2)	$0	($427)

Fair_Value_Measurements_Schedu

Fair Value Measurements - Schedule of Fair Value Assets and Liabilities Measured on Recurring Basis (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	($54,075)	$5,454
Money Market Funds Asset (Liability) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	1,035	1,035
Commodity Derivative Contracts [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	0	9,765
Fair value of assets and liabilities measured on recurring basis	-55,110	-5,346
Commodity Derivative Contracts Asset [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	-8,986	-11,910
Commodity Derivative Contracts Liability [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	8,986	11,910
Level 1 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	0	'
Level 1 [Member] | Money Market Funds Asset (Liability) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	0	'
Level 1 [Member] | Commodity Derivative Contracts [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	0	'
Fair value of assets and liabilities measured on recurring basis	0	'
Level 2 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	1,035	1,035
Level 2 [Member] | Money Market Funds Asset (Liability) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	1,035	1,035
Level 2 [Member] | Commodity Derivative Contracts [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	0	'
Fair value of assets and liabilities measured on recurring basis	0	'
Level 3 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	-55,110	4,419
Level 3 [Member] | Money Market Funds Asset (Liability) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	0	'
Level 3 [Member] | Commodity Derivative Contracts [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of assets and liabilities measured on recurring basis	8,986	21,675
Fair value of assets and liabilities measured on recurring basis	($64,096)	($17,256)

Fair_Value_Measurements_Schedu1

Fair Value Measurements - Schedule of Valuation Process and Unobservable Inputs (Detail) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Fair Value, Derivative Asset (Liability)	($55,110)
Bbl [Member] | Derivative Liabilities [Member] | Crude Oil [Member] | Swap [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Fair Value, Derivative Asset (Liability)	-47,633
Derivative assets, Valuation Technique	'Discounted cash flow
Unobservable Input	'Forward price curve-swaps
Bbl [Member] | Derivative Liabilities [Member] | Crude Oil [Member] | Costless Collar [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Fair Value, Derivative Asset (Liability)	-520
Derivative assets, Valuation Technique	'Option model
Unobservable Input	'Forward price curve- costless collar option value
MMBtu [Member] | Derivative Liabilities [Member] | NGL [Member] | Swap [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Fair Value, Derivative Asset (Liability)	-3,890
Derivative assets, Valuation Technique	'Discounted cash flow
Unobservable Input	'Forward price curve-swaps
MMBtu [Member] | Derivative Liabilities [Member] | Natural Gas [Member] | Costless Collar [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Fair Value, Derivative Asset (Liability)	-818
Derivative assets, Valuation Technique	'Option model
Unobservable Input	'Forward price curve- costless collar option value
MMBtu [Member] | Derivative Liabilities [Member] | Natural Gas [Member] | Natural Gas Swaps [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Fair Value, Derivative Asset (Liability)	-4,779
Derivative assets, Valuation Technique	'Discounted cash flow
Unobservable Input	'Forward price curve-swaps
MMBtu [Member] | Derivative Assets [Member] | NGL [Member] | Swap [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Fair Value, Derivative Asset (Liability)	2,509
Derivative assets, Valuation Technique	'Discounted cash flow
Unobservable Input	'Forward price curve-swaps
MMBtu [Member] | Derivative Assets [Member] | Natural Gas [Member] | Costless Collar [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Fair Value, Derivative Asset (Liability)	$21
Derivative assets, Valuation Technique	'Option model
Unobservable Input	'Forward price curve- costless collar option value
Minimum [Member] | Bbl [Member] | Derivative Liabilities [Member] | Crude Oil [Member] | Swap [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	90.08
Minimum [Member] | Bbl [Member] | Derivative Liabilities [Member] | Crude Oil [Member] | Costless Collar [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	-2.3
Minimum [Member] | MMBtu [Member] | Derivative Liabilities [Member] | NGL [Member] | Swap [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	0.28
Minimum [Member] | MMBtu [Member] | Derivative Liabilities [Member] | Natural Gas [Member] | Costless Collar [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	-0.3
Minimum [Member] | MMBtu [Member] | Derivative Liabilities [Member] | Natural Gas [Member] | Natural Gas Swaps [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	3.97
Minimum [Member] | MMBtu [Member] | Derivative Assets [Member] | NGL [Member] | Swap [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	0.29
Minimum [Member] | MMBtu [Member] | Derivative Assets [Member] | Natural Gas [Member] | Costless Collar [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	-0.22
Maximum [Member] | Bbl [Member] | Derivative Liabilities [Member] | Crude Oil [Member] | Swap [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	105.17
Maximum [Member] | Bbl [Member] | Derivative Liabilities [Member] | Crude Oil [Member] | Costless Collar [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	0.34
Maximum [Member] | MMBtu [Member] | Derivative Liabilities [Member] | NGL [Member] | Swap [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	2.21
Maximum [Member] | MMBtu [Member] | Derivative Liabilities [Member] | Natural Gas [Member] | Costless Collar [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	0.24
Maximum [Member] | MMBtu [Member] | Derivative Liabilities [Member] | Natural Gas [Member] | Natural Gas Swaps [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	4.59
Maximum [Member] | MMBtu [Member] | Derivative Assets [Member] | NGL [Member] | Swap [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	1.36
Maximum [Member] | MMBtu [Member] | Derivative Assets [Member] | Natural Gas [Member] | Costless Collar [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	0.16
Weighted Average [Member] | Bbl [Member] | Derivative Liabilities [Member] | Crude Oil [Member] | Swap [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	96.98
Weighted Average [Member] | Bbl [Member] | Derivative Liabilities [Member] | Crude Oil [Member] | Costless Collar [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	0.94
Weighted Average [Member] | MMBtu [Member] | Derivative Liabilities [Member] | NGL [Member] | Swap [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	0.94
Weighted Average [Member] | MMBtu [Member] | Derivative Liabilities [Member] | Natural Gas [Member] | Costless Collar [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	0.03
Weighted Average [Member] | MMBtu [Member] | Derivative Liabilities [Member] | Natural Gas [Member] | Natural Gas Swaps [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	4.27
Weighted Average [Member] | MMBtu [Member] | Derivative Assets [Member] | NGL [Member] | Swap [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	0.59
Weighted Average [Member] | MMBtu [Member] | Derivative Assets [Member] | Natural Gas [Member] | Costless Collar [Member]	'
Fair Value Assets And Liabilities Measured On Unobservable Inputs [Line Items]	'
Forward Price Curve	0

Fair_Value_Measurements_Additi

Fair Value Measurements - Additional Information (Detail) (USD $)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair value of its derivative instruments	$1,300,000
Fair market value of total debt	1,870,000,000
Carrying amount of debt	$1,800,000,000

Fair_Value_Measurements_Schedu2

Fair Value Measurements - Schedule of Fair Value Assets and Liabilities Classified (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'	'	'
Settlements	$5,714	($3,289)	$13,651	($5,291)
Derivatives Asset (Liability) [Member]	'	'	'	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'	'	'
Balance, Beginning	'	'	4,419	20,664
Included in Earnings	'	'	-73,180	34,508
Settlements	'	'	13,651	-5,291
Transfers in and out of Level 3	'	'	0	'
Balance, Ending	($55,110)	$49,881	($55,110)	$49,881

Asset_Retirement_Obligations_S

Asset Retirement Obligations - Schedule of Asset Retirement Obligations (Detail) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
ARO at the beginning of the period	$13,057
Liabilities incurred during period	2,334
Liabilities settled during period	0
Accretion expense	495
ARO at the end of the period	$15,886

Asset_Retirement_Obligations_A

Asset Retirement Obligations - Additional Information (Detail) (USD $)	Jun. 30, 2014
In Millions, unless otherwise specified
Asset Retirement Obligation Disclosure [Abstract]	'
Current portion of ARO	$4
Long-term portion of ARO	$11.90

Debt_and_Credit_Agreements_Add

Debt and Credit Agreements - Additional Information (Detail) (USD $)

3 Months Ended

6 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

5-May-14

Jun. 30, 2014

5-May-14

Apr. 02, 2014

Jun. 30, 2014

2-May-13

Jun. 30, 2014

Nov. 15, 2013

Jun. 30, 2014

29-May-14

Minimum [Member]

Maximum [Member]

London Interbank Offered Rate (LIBOR) [Member]

Alternative Base Rate [Member]

Alternative Base Rate [Member]

Amended and Restated Senior Revolving Credit Agreement [Member]

Amended and Restated Senior Revolving Credit Agreement [Member]

Credit Facilities [Member]

Credit Facilities [Member]

9.500% Senior Notes due 2018 [Member]

9.500% Senior Notes due 2018 [Member]

9.500% Senior Notes due 2018 [Member]

9.500% Senior Notes due 2018 [Member]

5.625% Senior Notes due 2021 [Member]

5.625% Senior Notes due 2021 [Member]

5.875% Senior Notes due 2022 [Member]

5.875% Senior Notes due 2022 [Member]

5.875% Senior Notes due 2024 [Member]

5.875% Senior Notes due 2024 [Member]

Ratio

Maximum [Member]

Minimum [Member]

Maximum [Member]

London Interbank Offered Rate (LIBOR) [Member]

Accounts Payable and Accrued Liabilities [Member]

Amended and Restated Senior Revolving Credit Agreement [Member]

Minimum [Member]

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current borrowing base

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$800,000,000

'

'

'

'

'

'

Borrowing base increased

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

950,000,000

'

'

'

'

'

'

Maximum credit amount increased under credit agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,500,000,000

'

'

'

'

'

'

Amount outstanding

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

Available borrowing capacity

'

'

'

'

'

'

'

'

800,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, interest rate, stated percentage

'

'

'

'

'

2.50%

0.50%

1.50%

'

1.50%

'

'

9.50%

'

'

'

'

5.63%

'

5.88%

'

5.88%

Weighted average borrowing rate under Restated Revolver

2.65%

2.38%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest expense on Credit Facility

'

'

'

'

'

'

'

'

'

'

900,000

1,000,000

'

'

'

'

'

'

'

'

'

'

Commitment fees on Credit Facility

'

'

'

'

'

'

'

'

'

'

600,000

1,400,000

'

'

'

'

'

'

'

'

'

'

Pre-tax SEC PV-10 reserve value, percentage

'

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pledge of membership and limited partnership interests percentage

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current ratio

'

'

'

0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Leverage ratio

'

'

'

'

0.04

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current ratio

'

2.90%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Leverage ratio

'

2.80%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt maturity date

'

'

'

'

'

'

'

'

'

'

'

'

'

'Senior Notes due 2018

'

'

'Senior Notes due 2021

'

'Senior Notes due 2022

'

'Senior Notes due 2024

'

Redemption term of long-term debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'104.75% of the principal amount, plus accrued and unpaid interest

'

'

'

'

'

'

'

'

Redemption of debt instrument

'

'

'

'

'

'

'

'

'

'

'

'

210,600,000

'

'

'

'

'

'

'

'

'

Redemption of debt instrument (Call premium)

'

'

'

'

'

'

'

'

'

'

'

'

9,500,000

'

'

'

'

'

'

'

'

'

Accrued and unpaid interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,100,000

'

'

'

'

'

'

'

Unamortized debt issuance cost

'

'

'

'

'

'

'

'

'

'

'

'

'

3,100,000

'

'

'

'

'

'

'

'

Issuance of aggregate principal amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

700,000,000

'

600,000,000

'

500,000,000

Total outstanding borrowings

$1,800,000,000

$1,800,000,000

$1,500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average borrowing rate

6.04%

6.04%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income_Taxes_Additional_Inform

Income Taxes - Additional Information (Detail) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'	'	'	'	'
Effective tax rate	36.70%	36.20%	35.70%	35.10%	'
Unrecognized tax benefits	$0	'	$0	'	$0
Deferred tax liability	$159,968,000	'	$159,968,000	'	$136,407,000

Commitments_and_Contingencies_1

Commitments and Contingencies - Additional Information (Detail) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
Oil and Gas Delivery Commitments and Contracts [Line Items]	'
Accrued deficiency fees	$4.10
Outstanding commitments	21.8
Minimum remaining contractual commitment	$9.40
Oil Commitments (MMBbls) [Member]	'
Oil and Gas Delivery Commitments and Contracts [Line Items]	'
Oil and gas delivery transportation commitments	5.3
Natural Gas Commitments (MMBtus) [Member]	'
Oil and Gas Delivery Commitments and Contracts [Line Items]	'
Oil and gas delivery transportation commitments	612,000,000

Commitments_and_Contingencies_2

Commitments and Contingencies - Future Obligations Under Firm Gas and Oil Transportation Agreements (Detail) (USD $)	Jun. 30, 2014
In Thousands, unless otherwise specified
Oil And Gas Delivery Commitments And Contracts Additional Information [Abstract]	'
2014	$10,352
2015	22,818
2016	22,132
2017	21,708
2018	18,159
Thereafter	102,406
Total future obligations	$197,575

Equity_Schedule_of_Basic_and_D

Equity - Schedule of Basic and Diluted Weighted Average Shares Outstanding (Detail)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Equity [Abstract]	'	'	'	'
Basic weighted average number of shares outstanding	61,452	58,990	61,416	55,879
Dilution effect of stock option and restricted shares at the end of the period	165	211	183	286
Diluted weighted average number of shares outstanding	61,617	59,201	61,599	56,165
Anti-dilutive stock awards and shares	0	6	5	2

Equity_Additional_Information_

Equity - Additional Information (Detail) (USD $)	6 Months Ended
In Thousands, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Equity [Line Items]	'	'
Common stock price per share	$42.50	'
Underwriting discount and structuring fee per share, net	$40.80	'
Net proceeds from equity issue	'	$329,152
Underwriters Over-Allotment Option [Member]	'	'
Equity [Line Items]	'	'
Public offering of common stock	1,050,000	'
Common Stock [Member]	'	'
Equity [Line Items]	'	'
Public offering of common stock	7,000,000	'
Net proceeds from equity issue	286,300	'
Common Stock [Member] | Underwriters Over-Allotment Option [Member]	'	'
Equity [Line Items]	'	'
Net proceeds from equity issue	$43,000	'

StockBased_Compensation_and_Em2

Stock-Based Compensation and Employee Benefits - Schedule of Stock-Based Compensation Expense (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]	'	'	'	'
Total stock-based compensation expense	$4,158	$2,303	$7,639	$5,041
Capitalized in oil and gas properties	-123	-74	-246	-148
Net stock-based compensation expense	$4,035	$2,229	$7,393	$4,893

StockBased_Compensation_and_Em3

Stock-Based Compensation and Employee Benefits - Additional Information (Detail) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Stock compensation expense recorded	$4,035,000	$2,229,000	$7,393,000	$4,893,000
Stock-based compensation expense associated with PSU	4,158,000	2,303,000	7,639,000	5,041,000
Postretirement Health Care Plans [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Liability related to prior service of employees	'	'	300,000	'
Employee Stock Option [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Stock compensation expense recorded	2,300,000	'	5,000,000	'
Unrecognized compensation expense	15,900,000	'	15,900,000	'
Performance Shares [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Unrecognized compensation expense	20,200,000	'	20,200,000	'
Stock-based compensation expense associated with PSU	$1,800,000	'	$2,600,000	'
PSUs performance period, in years	'	'	'3 years	'
Number of shares vested range, percentage of targeted amounts	'	'	200.00%	'

Guarantor_Subsidiaries_Additio

Guarantor Subsidiaries - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2014
Guarantees [Abstract]	'
Number of subsidiaries with restricted assets that exceed 25% of net assets	'None
Maximum percentage of non-transferrable net assets	25.00%