Rosetta Resources 10-Q 4 May 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015	Apr. 24, 2015
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Trading Symbol	ROSE
Entity Registrant Name	ROSETTA RESOURCES INC.
Entity Central Index Key	1340282
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		75,696,189

Consolidated_Balance_Sheet

Consolidated Balance Sheet (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Current assets:
Cash and cash equivalents	$9,127	$34,397
Accounts receivable	92,471	117,070
Derivative instruments	210,324	221,250
Prepaid expenses	9,107	8,142
Other current assets	4,249	3,535
Total current assets	325,278	384,394
Oil and natural gas properties using the full cost method of accounting:
Proved properties	5,518,122	5,337,537
Unproved/unevaluated properties, not subject to amortization	521,842	550,979
Gathering systems and compressor stations	286,867	285,989
Other fixed assets	34,087	34,339
Total property and equipment, gross	6,360,918	6,208,844
Accumulated depreciation, depletion and amortization, including impairment	-3,332,570	-2,434,003
Total property and equipment, net	3,028,348	3,774,841
Other assets:
Debt issuance costs	25,731	25,741
Deferred tax asset	85,385
Derivative instruments	61,645	65,419
Other long-term assets	68	272
Total other assets	172,829	91,432
Total assets	3,526,455	4,250,667
Current liabilities:
Accounts payable and accrued liabilities	179,339	179,353
Royalties and other payables	64,802	98,972
Deferred income taxes	72,565	72,445
Total current liabilities	316,706	350,770
Long-term liabilities:
Long-term debt	1,840,000	2,000,000
Deferred income taxes		207,854
Other long-term liabilities	27,495	22,930
Total liabilities	2,184,201	2,581,554
Commitments and Contingencies (Note 9)
Stockholders' equity:
Preferred stock, $0.001 par value; authorized 5,000,000 shares; no shares issued in 2015 or 2014
Common stock, $0.001 par value; authorized 150,000,000 shares; issued 74,684,429 shares and 62,306,601 shares at March 31, 2015 and December 31, 2014, respectively	75	62
Additional paid-in capital	1,405,916	1,192,836
Treasury stock, at cost; 801,651 shares and 788,493 shares at March 31, 2015 and December 31, 2014, respectively	-27,702	-27,414
Accumulated other comprehensive loss	-224	-234
(Accumulated deficit) retained earnings	-35,811	503,863
Total stockholders' equity	1,342,254	1,669,113
Total liabilities and stockholders' equity	$3,526,455	$4,250,667

Consolidated_Balance_Sheet_Par

Consolidated Balance Sheet (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
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	74,684,429	62,306,601
Treasury stock, shares	801,651	788,493

Consolidated_Statement_of_Oper

Consolidated Statement of Operations (Unaudited) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Revenues:
Oil sales	$62,517	$131,677
NGL sales	25,895	55,295
Natural gas sales	37,229	51,379
Derivative instruments	47,503	-23,785
Total revenues	173,144	214,566
Operating costs and expenses:
Lease operating expense	21,822	19,521
Treating and transportation	24,414	20,677
Taxes, other than income	8,679	10,206
Depreciation, depletion and amortization	100,757	74,775
Impairment of oil and gas properties	798,133
Reserve for commercial disputes	9,200
General and administrative costs	21,920	19,538
Total operating costs and expenses	984,925	144,717
Operating (loss) income	-811,781	69,849
Other expense (income):
Interest expense, net of interest capitalized	22,048	15,290
Interest income	-1	-12
Other (income) expense, net	-185	151
Total other expense	21,862	15,429
(Loss) income before provision for income taxes	-833,643	54,420
Income tax (benefit) expense	-293,969	19,177
Net (loss) income	($539,674)	$35,243
(Loss) earnings per share:
Basic	($8.42)	$0.57
Diluted	($8.42)	$0.57
Weighted average shares outstanding:
Basic	64,082	61,380
Diluted	64,082	61,547

Consolidated_Statement_of_Comp

Consolidated Statement of Comprehensive Income (Unaudited) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Statement of Comprehensive Income [Abstract]
Net (loss) income	($539,674)	$35,243
Other comprehensive income (loss):
Postretirement medical benefits prior service benefit, net of income taxes of ($5) and ($2), respectively	10	3
Other comprehensive income	10	3
Comprehensive (loss) income	($539,664)	$35,246

Consolidated_Statement_of_Comp1

Consolidated Statement of Comprehensive Income (Unaudited) (Parenthetical) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Statement of Comprehensive Income [Abstract]
Postretirement medical benefits prior service benefit, income tax (expense) benefit	($5)	($2)

Consolidated_Statement_of_Cash

Consolidated Statement of Cash Flows (Unaudited) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash flows from operating activities:
Net (loss) income	($539,674)	$35,243
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	100,757	74,775
Impairment of oil and gas properties	798,133
Deferred income taxes	-293,969	18,604
Amortization of deferred loan fees recorded as interest expense	1,020	984
Stock-based compensation expense	2,950	3,358
Loss due to change in fair value of derivative instruments	14,700	15,848
Change in operating assets and liabilities:
Accounts receivable	24,599	-7,625
Prepaid expenses	-427	1,956
Other current assets	-714	-880
Long-term assets	204	43
Accounts payable and accrued liabilities	34,952	3,264
Royalties and other payables	-34,170	5,277
Other long-term liabilities	-690	377
Net cash provided by operating activities	107,671	151,224
Cash flows from investing activities:
Acquisitions of oil and gas assets		-79,015
Additions to oil and gas assets	-176,078	-268,836
Disposals of oil and gas assets	558	8
Net cash used in investing activities	-175,520	-347,843
Cash flows from financing activities:
Borrowings on Credit Facility	110,000	80,000
Payments on Credit Facility	-270,000	-20,000
Proceeds from issuance of common stock	204,415
Deferred loan fees	-1,548
Proceeds from stock options exercised		61
Purchases of treasury stock	-288	-2,133
Excess tax benefit from share-based awards		22
Net cash provided by financing activities	42,579	57,950
Net decrease in cash	-25,270	-138,669
Cash and cash equivalents, beginning of period	34,397	193,784
Cash and cash equivalents, end of period	9,127	55,115
Supplemental disclosures:
Capital expenditures included in Accounts payable and accrued liabilities	94,340	206,867
Operating liabilities settled in stock	$6,419

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 Dec. 31, 2014	$1,669,113	$62	$1,192,836	($27,414)	($234)	$503,863
Balance, Treasury Stock, Shares at Dec. 31, 2014	788,493			788,493
Balance, Common Stock Shares at Dec. 31, 2014	62,306,601	62,306,601
Issuance of common stock	204,415	12	204,403
Issuance of common stock, shares		12,000,000
Treasury stock - employee tax payment	-288			-288
Treasury Stock, Shares, Acquired				13,158
Tax impact of stock awards	-845		-845
Stock-based compensation	3,103		3,103
Vesting of restricted stock	0	0	0	0	0	0
Vesting of restricted stock, Shares		122,247
Operating liabilities settled in stock	6,420	1	6,419
Operating liabilities settled in stock, shares		255,581
Comprehensive income (loss)	-539,664				10	-539,674
Balance at Mar. 31, 2015	$1,342,254	$75	$1,405,916	($27,702)	($224)	($35,811)
Balance, Treasury Stock, Shares at Mar. 31, 2015	801,651			801,651
Balance, Common Stock Shares at Mar. 31, 2015	74,684,429	74,684,429

Organization_and_Operations_of

Organization and Operations of the Company	3 Months Ended
	Mar. 31, 2015
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, 2014 (“2014 Annual Report”).

Summary_of_Significant_Account

Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2015
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 2014 Annual Report. There have been no changes to the Company’s significant accounting policies since December 31, 2014.
	Recent Accounting Developments
	In January 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2015-01, Income Statement - Extraordinary and Unusual Items. The ASU removes the concept of extraordinary items from GAAP. Under existing guidance, an entity is required to separately disclose extraordinary items, net of tax, in the income statement after income from continuing operations if an event or transaction is of an unusual nature and occurs infrequently. This separate, net-of-tax presentation will no longer be allowed, and the pronouncement is effective for interim and annual reporting periods beginning after December 15, 2015. 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	3 Months Ended
	Mar. 31, 2015
Extractive Industries [Abstract]
Property and Equipment	(3) Property and Equipment
	The Company’s total property and equipment consists of the following:
		March 31, 2015			December 31, 2014
		(In thousands)
	Proved properties	$	5,518,122		$	5,337,537
	Unproved/unevaluated properties		521,842			550,979
	Gathering systems and compressor stations		286,867			285,989
	Other fixed assets		34,087			34,339
	Total		6,360,918			6,208,844
	Less: Accumulated depreciation, depletion and amortization, including impairment		(3,332,570	)		(2,434,003	)
	Total property and equipment, net	$	3,028,348		$	3,774,841
	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 $83.8 million.
	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 $1.6 million of internal costs for the three months ended March 31, 2015 and 2014, respectively.
	Oil and gas properties include unevaluated property costs of $521.8 million and $551.0 million as of March 31, 2015 and December 31, 2014, 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.
	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 March 31, 2015, which were based on a West Texas Intermediate oil price of $79.21 per Bbl and a Henry Hub natural gas price of $3.88 per MMBtu (adjusted for basis and quality differentials), respectively. Utilizing these prices, the calculated ceiling amount was less than the net capitalized cost of oil and natural gas properties as of March 31, 2015, and as a result, a pre-tax write-down of $798.1 million was recorded at March 31, 2015. Additional material write-downs of the Company’s oil and gas properties will occur in subsequent quarters in the event that oil and natural gas prices remain at current depressed levels, or if the Company experiences significant downward adjustments to its estimated proved reserves.

Commodity_Derivative_Contracts

Commodity Derivative Contracts	3 Months Ended
	Mar. 31, 2015
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, basis 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 March 31, 2015, 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	2015	Costless Collar			7,778				2,139,001	$	55	$	84.79
	Crude oil	2015	Swap			12,000				3,300,000		89.81
	Crude oil	2016	Swap			6,000				2,196,000		90.28
										7,635,001
	Product	Settlement	Derivative		Notional				Total		Average
		Period	Instrument		Daily				Notional		Fixed
					Volume				Volume		Prices
					(Bbls)				(Bbls)		per Bbl
	NGL-Ethane	2015	Swap			3,476				955,952	$	11.31
	NGL-Propane	2015	Swap			1,750				481,250		43.35
	NGL-Isobutane	2015	Swap			617				169,583		53.05
	NGL-Normal Butane	2015	Swap			579				159,107		52.53
	NGL-Pentanes Plus	2015	Swap			579				159,107		77.72
										1,924,999
	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	2015	Costless Collar			50,000				13,750,000	$	3.60	$	5.04
	Natural gas	2016	Costless Collar			40,000				14,640,000		3.5		5.58
	Natural gas	2015	Swap			50,000				13,750,000		4.13
	Natural gas	2016	Swap			30,000				10,980,000		4.04
										53,120,000
	As of March 31, 2015, 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 2014 Annual Report. As of March 31, 2015, the Company had no deposits for collateral regarding commodity derivative positions.
	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 March 31, 2015 and December 31, 2014, respectively:
			Asset (Liability) Fair Value
			March 31, 2015				December 31, 2014
	Commodity derivative contracts	Location on Consolidated Balance Sheet	(In thousands)
	Oil	Derivative instruments - current assets	$	146,443			$	151,363
	Oil	Derivative instruments - non-current assets		47,863				54,187
	NGL	Derivative instruments - current assets		26,889				35,992
	Natural gas	Derivative instruments - current assets		36,992				33,895
	Natural gas	Derivative instruments - non-current assets		13,782				11,232
	Total derivative fair value, net, not designated as hedging instruments		$	271,969			$	286,669
	The following table sets forth the type and amount of derivative gains and losses included in Derivative instruments in the Consolidated Statement of Operations for the three months ended March 31, 2015 and 2014, respectively:
			Three Months Ended March 31,
	Location on Consolidated		2015				2014
	Statement of Operations	Description of Gain (Loss)	(In thousands)
	Derivative instruments	Realized gain (loss) recognized in income	$	62,203			$	(7,937	)
	Derivative instruments	Unrealized loss recognized in income		(14,700	)			(15,848	)
		Total commodity derivative gain (loss) recognized in income	$	47,503			$	(23,785	)

Fair_Value_Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2015
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.
	As defined in the guidance of the 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 March 31, 2015
			Level 1			Level 2			Level 3			Netting (1)			Total
			(In thousands)
	Assets:
	Commodity derivative contracts		$	—		$	—		$	272,726		$	(757	)	$	271,969
	Liabilities:
	Commodity derivative contracts			—			—			(757	)		757			—
	Total fair value		$	—		$	—		$	271,969		$	—		$	271,969
			Fair value as of December 31, 2014
			Level 1			Level 2			Level 3			Netting (1)			Total
			(In thousands)
	Assets:
	Commodity derivative contracts		$	—		$	—		$	289,878		$	(3,209	)	$	286,669
	Liabilities:
	Commodity derivative contracts			—			—			(3,209	)		3,209			—
	Total fair value		$	—		$	—		$	286,669		$	—		$	286,669
	-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 March 31, 2015 (in thousands):
						Valuation			Range						Weighted
	Level 3 Instrument		Asset (Liability)			Technique		Unobservable Input	Minimum			Maximum			Average
	Oil swaps		$	185,817		Discounted cash flow		Forward price curve-swaps	$	48.18		$	62.53		$	55.99
	Oil costless collars			8,489		Option model		Forward price curve-costless collar option value		(0.41	)		5.16			3.97
	NGL swaps			26,889		Discounted cash flow		Forward price curve-swaps		0.17			1.17			0.43
	Natural gas swaps			29,460		Discounted cash flow		Forward price curve-swaps		(0.10	)		3.36			2.9
	Natural gas costless collars			21,314		Option model		Forward price curve-costless collar option value		(0.07	)		1.27			0.75
	Total		$	271,969
	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 a downward adjustment to the fair value of its derivative instruments in the amount of $0.6 million as of March 31, 2015 due to nonperformance risk.
	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, 2015		$	286,669
	Total Gains (Realized or Unrealized):
	Included in Earnings			47,503
	Purchases, Issuances and Settlements:
	Settlements			(62,203	)
	Transfers in and out of Level 3			—
	Balance at March 31, 2015		$	271,969
			Derivative Asset
			(Liability)
			(In thousands)
	Balance at January 1, 2014		$	4,419
	Total Losses (Realized or Unrealized):
	Included in Earnings			(23,785	)
	Purchases, Issuances and Settlements:
	Settlements			7,937
	Transfers in and out of Level 3			—
	Balance at March 31, 2014		$	(11,429	)
	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 March 31, 2015, the carrying value of cash and cash equivalents, 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) and borrowings under the Credit Facility (defined below). The fair values of the Company’s Senior Notes are based upon unadjusted quoted market prices and are considered Level 1 instruments. The Company’s borrowings under the Credit Facility approximate fair value as the interest rates are variable and reflective of current market rates, and are therefore considered a Level 1 instrument. As of March 31, 2015, the carrying amount of total debt was $1.84 billion and the estimated fair value of total debt was $1.74 billion.

Asset_Retirement_Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2015
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:
		Three Months Ended
		March 31, 2015
		(In thousands)
	ARO as of December 31, 2014	$	19,957
	Liabilities incurred during period		62
	Liabilities settled during period		(328	)
	Accretion expense		323
	ARO as of March 31, 2015	$	20,014
	As of March 31, 2015, the $0.2 million current portion of the total ARO is included in Accrued liabilities, and the $19.8 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	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Debt and Credit Agreements	(7) Debt and Credit Agreements
	Senior Secured Revolving Credit Facility. On February 18, 2015, the Company entered into the Ninth Amendment to the 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, modified the Company’s financial covenant requirements by replacing its debt to earnings before interest expense, income taxes and noncash items, such as depreciation, depletion, amortization and impairment (“EBITDA”) leverage ratio with two additional covenants: a senior secured leverage ratio and an interest coverage ratio, both described below.
	As of March 31, 2015, the Company had $40.0 million outstanding with $760.0 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 months ended March 31, 2015 was 1.96%, exclusive of commitment fees. For the three months ended March 31, 2015, interest expense was $0.9 million and commitment fees were $0.6 million 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 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 senior secured leverage ratio of secured debt to EBITDA, of not greater than 2.5 to 1.0, and an interest coverage ratio of EBITDA to gross interest, of not less than 2.5 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 March 31, 2015, the Company’s current ratio was 2.8, senior secured leverage ratio was 0.1 and interest coverage ratio was 6.0. 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 due 2018, 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.
	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 March 31, 2015, the Company had total indebtedness of $1.84 billion, and for the three months ended March 31, 2015, the Company’s weighted average borrowing rate was 5.55%, inclusive of interest and commitment fees.
	Subsequent Event. On April 21, 2015, the Company’s semi-annual borrowing base redetermination was completed for the Credit Facility and the Company’s borrowing base and elected commitment amount were reaffirmed by the Company’s lenders at $950.0 million and $800.0 million, respectively.

Income_Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	(8) Income Taxes
	The Company’s effective tax rate for the three months ended March 31, 2015 and 2014 was 35.3% and 35.2%, respectively. The provision for income taxes 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 March 31, 2015 and December 31, 2014, the Company had no unrecognized tax benefits. The Company does not anticipate that the balance of unrecognized tax benefits will significantly change within the next twelve months due to the settlement of audits or expiration of statutes of limitations.
	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 March 31, 2015, the Company had a net deferred tax asset of $12.8 million resulting primarily from differences between the book basis and tax basis of the Company’s oil and natural gas properties. The Company believes this deferred tax asset will be fully realized through the generation of future taxable income, and because it is more likely than not to be realized, no valuation allowance has been provided against this deferred tax asset. However, the realizable amount of the deferred tax asset could be reduced in the near term if estimates of future taxable income during the carryforward period are reduced.

Commitments_and_Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2015
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, including an aggregate minimum commitment to deliver 4.1 MMBbls of oil by the end of 2017 and 575 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. However, 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 may expose the Company to additional volume deficiency payments. As of March 31, 2015, the Company has accrued deficiency fees of $4.9 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 March 31, 2015 are as follows:
		March 31, 2015
		(In thousands)
	2015	$	16,664
	2016		22,132
	2017		21,708
	2018		18,159
	2019		15,900
	Thereafter		86,507
	Total future obligations	$	181,070
	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 March 31, 2015, the Company had no outstanding drilling rig commitments with a term greater than one year, and the minimum contractual commitments due in the next twelve months are $7.0 million. For the three months ended March 31, 2015, the Company recorded approximately $15.8 million in rig termination fees. As of March 31, 2015, the Company’s minimum contractual commitments due in the next twelve months for other field services were $5.2 million. Payments under these commitments are accounted for as capital additions to oil and gas properties.
	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.
	Commercial Disputes. For the three months ended March 31, 2015, the Company recorded a reserve of $9.2 million related to a commercial dispute concerning the calculation of royalty amounts earned and royalty deductions taken over specified periods in 2009 through 2013. The dispute arose in the third quarter of 2014 and the Company has been in ongoing discussions with those royalty holders regarding their royalty claim. The Company’s total recorded reserve of $15.0 million represents its expected loss exposure associated with this dispute and the final resolution of this matter is expected to occur in the second quarter of 2015. The reserve for this contingency is reported in Reserve for commercial disputes in the Consolidated Statement of Operations and is included in Accounts payable and accrued liabilities in the Consolidated Balance Sheet.

Equity

Equity	3 Months Ended
	Mar. 31, 2015
Equity [Abstract]
Equity	(10) Equity
	Earnings per Share. Basic earnings per share (“EPS”) is calculated by dividing 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 March 31,
			2015		2014
			(In thousands)
	Basic weighted average number of shares outstanding			64,082		61,380
	Dilution effect of stock options and restricted shares at the end of the period (1)			—		167
	Diluted weighted average number of shares outstanding			64,082		61,547
	Anti-dilutive stock awards and shares			566		9
	-1	Because the Company recognized a net loss for the three months ended March 31, 2015, no unvested stock awards and options were included in computing earnings per share because the effect was anti-dilutive.
	Common Stock Offering. On March 13, 2015, the Company completed its public offering of 12,000,000 shares of common stock at a price to the public of $17.20 per share ($17.04 per share, net of underwriting discount) for net proceeds of approximately $204.5 million.
	Subsequent Event. The Company also received net proceeds of approximately $30.7 million in connection with the underwriters’ full exercise of their over-allotment option to purchase an additional 1,800,000 shares of common stock, which closed on April 8, 2015.

StockBased_Compensation_and_Em

Stock-Based Compensation and Employee Benefits	3 Months Ended
	Mar. 31, 2015
Disclosure of Compensation Related Costs, Share-based 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 March 31,
		2015			2014
		(In thousands)
	Total stock-based compensation expense	$	3,103		$	3,481
	Capitalized in oil and gas properties		(153	)		(123	)
	Net stock-based compensation expense	$	2,950		$	3,358
	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 months ended March 31, 2015, the Company recorded stock-based compensation expense of approximately $2.9 million related to these equity awards. As of March 31, 2015, unrecognized stock-based compensation expense related to unvested restricted stock was approximately $21.2 million.
	Stock-based compensation expense associated with the PSUs granted to management is recognized over a three-year performance period. For the three months ended March 31, 2015, the Company recognized compensation expense of $0.2 million associated with the PSUs. At the current fair value as of March 31, 2015, 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 $13.0 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 2015 annual meeting under the heading “Compensation Discussion and Analysis” and the Company’s 2014 Annual Report.
	Postretirement Health Care. The Company has a postretirement medical benefit plan covering eligible employees and their eligible dependents. The Company recognizes periodic postretirement benefits costs as a component of General and administrative costs. For both the three months ended March 31, 2015 and 2014, this expense was immaterial.

Guarantor_Subsidiaries

Guarantor Subsidiaries	3 Months Ended
	Mar. 31, 2015
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)	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
Recent Accounting Developments	Recent Accounting Developments
	In January 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2015-01, Income Statement - Extraordinary and Unusual Items. The ASU removes the concept of extraordinary items from GAAP. Under existing guidance, an entity is required to separately disclose extraordinary items, net of tax, in the income statement after income from continuing operations if an event or transaction is of an unusual nature and occurs infrequently. This separate, net-of-tax presentation will no longer be allowed, and the pronouncement is effective for interim and annual reporting periods beginning after December 15, 2015. 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)	3 Months Ended
	Mar. 31, 2015
Extractive Industries [Abstract]
Schedule of Total Property, Plant and Equipment, Net	The Company’s total property and equipment consists of the following:
		March 31, 2015			December 31, 2014
		(In thousands)
	Proved properties	$	5,518,122		$	5,337,537
	Unproved/unevaluated properties		521,842			550,979
	Gathering systems and compressor stations		286,867			285,989
	Other fixed assets		34,087			34,339
	Total		6,360,918			6,208,844
	Less: Accumulated depreciation, depletion and amortization, including impairment		(3,332,570	)		(2,434,003	)
	Total property and equipment, net	$	3,028,348		$	3,774,841

Commodity_Derivative_Contracts1

Commodity Derivative Contracts (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	As of March 31, 2015, 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	2015	Costless Collar			7,778				2,139,001	$	55	$	84.79
	Crude oil	2015	Swap			12,000				3,300,000		89.81
	Crude oil	2016	Swap			6,000				2,196,000		90.28
										7,635,001
	Product	Settlement	Derivative		Notional				Total		Average
		Period	Instrument		Daily				Notional		Fixed
					Volume				Volume		Prices
					(Bbls)				(Bbls)		per Bbl
	NGL-Ethane	2015	Swap			3,476				955,952	$	11.31
	NGL-Propane	2015	Swap			1,750				481,250		43.35
	NGL-Isobutane	2015	Swap			617				169,583		53.05
	NGL-Normal Butane	2015	Swap			579				159,107		52.53
	NGL-Pentanes Plus	2015	Swap			579				159,107		77.72
										1,924,999
	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	2015	Costless Collar			50,000				13,750,000	$	3.60	$	5.04
	Natural gas	2016	Costless Collar			40,000				14,640,000		3.5		5.58
	Natural gas	2015	Swap			50,000				13,750,000		4.13
	Natural gas	2016	Swap			30,000				10,980,000		4.04
										53,120,000
Schedule of Derivative Instruments in Statement of Financial Position	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 March 31, 2015 and December 31, 2014, respectively:
			Asset (Liability) Fair Value
			March 31, 2015				December 31, 2014
	Commodity derivative contracts	Location on Consolidated Balance Sheet	(In thousands)
	Oil	Derivative instruments - current assets	$	146,443			$	151,363
	Oil	Derivative instruments - non-current assets		47,863				54,187
	NGL	Derivative instruments - current assets		26,889				35,992
	Natural gas	Derivative instruments - current assets		36,992				33,895
	Natural gas	Derivative instruments - non-current assets		13,782				11,232
	Total derivative fair value, net, not designated as hedging instruments		$	271,969			$	286,669
Schedule of Derivative Gains and Losses Included in Derivative Instrument in Consolidated Statement of Operations	The following table sets forth the type and amount of derivative gains and losses included in Derivative instruments in the Consolidated Statement of Operations for the three months ended March 31, 2015 and 2014, respectively:
			Three Months Ended March 31,
	Location on Consolidated		2015				2014
	Statement of Operations	Description of Gain (Loss)	(In thousands)
	Derivative instruments	Realized gain (loss) recognized in income	$	62,203			$	(7,937	)
	Derivative instruments	Unrealized loss recognized in income		(14,700	)			(15,848	)
		Total commodity derivative gain (loss) recognized in income	$	47,503			$	(23,785	)

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2015
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 March 31, 2015
			Level 1			Level 2			Level 3			Netting (1)			Total
			(In thousands)
	Assets:
	Commodity derivative contracts		$	—		$	—		$	272,726		$	(757	)	$	271,969
	Liabilities:
	Commodity derivative contracts			—			—			(757	)		757			—
	Total fair value		$	—		$	—		$	271,969		$	—		$	271,969
			Fair value as of December 31, 2014
			Level 1			Level 2			Level 3			Netting (1)			Total
			(In thousands)
	Assets:
	Commodity derivative contracts		$	—		$	—		$	289,878		$	(3,209	)	$	286,669
	Liabilities:
	Commodity derivative contracts			—			—			(3,209	)		3,209			—
	Total fair value		$	—		$	—		$	286,669		$	—		$	286,669
	-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 March 31, 2015 (in thousands):
						Valuation			Range						Weighted
	Level 3 Instrument		Asset (Liability)			Technique		Unobservable Input	Minimum			Maximum			Average
	Oil swaps		$	185,817		Discounted cash flow		Forward price curve-swaps	$	48.18		$	62.53		$	55.99
	Oil costless collars			8,489		Option model		Forward price curve-costless collar option value		(0.41	)		5.16			3.97
	NGL swaps			26,889		Discounted cash flow		Forward price curve-swaps		0.17			1.17			0.43
	Natural gas swaps			29,460		Discounted cash flow		Forward price curve-swaps		(0.10	)		3.36			2.9
	Natural gas costless collars			21,314		Option model		Forward price curve-costless collar option value		(0.07	)		1.27			0.75
	Total		$	271,969
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, 2015		$	286,669
	Total Gains (Realized or Unrealized):
	Included in Earnings			47,503
	Purchases, Issuances and Settlements:
	Settlements			(62,203	)
	Transfers in and out of Level 3			—
	Balance at March 31, 2015		$	271,969
			Derivative Asset
			(Liability)
			(In thousands)
	Balance at January 1, 2014		$	4,419
	Total Losses (Realized or Unrealized):
	Included in Earnings			(23,785	)
	Purchases, Issuances and Settlements:
	Settlements			7,937
	Transfers in and out of Level 3			—
	Balance at March 31, 2014		$	(11,429	)

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Asset Retirement Obligations	Activity related to the Company’s ARO is as follows:
		Three Months Ended
		March 31, 2015
		(In thousands)
	ARO as of December 31, 2014	$	19,957
	Liabilities incurred during period		62
	Liabilities settled during period		(328	)
	Accretion expense		323
	ARO as of March 31, 2015	$	20,014

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	3 Months Ended
	Mar. 31, 2015
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 March 31, 2015 are as follows:
		March 31, 2015
		(In thousands)
	2015	$	16,664
	2016		22,132
	2017		21,708
	2018		18,159
	2019		15,900
	Thereafter		86,507
	Total future obligations	$	181,070

Equity_Tables

Equity (Tables)	3 Months Ended
	Mar. 31, 2015
Equity [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 March 31,
			2015		2014
			(In thousands)
	Basic weighted average number of shares outstanding			64,082		61,380
	Dilution effect of stock options and restricted shares at the end of the period (1)			—		167
	Diluted weighted average number of shares outstanding			64,082		61,547
	Anti-dilutive stock awards and shares			566		9
	-1	Because the Company recognized a net loss for the three months ended March 31, 2015, no unvested stock awards and options were included in computing earnings per share because the effect was anti-dilutive.

StockBased_Compensation_and_Em1

Stock-Based Compensation and Employee Benefits (Tables)	3 Months Ended
	Mar. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Stock-Based Compensation Expense	As of the indicated dates, stock-based compensation expense consisted of the following:
		Three Months Ended March 31,
		2015			2014
		(In thousands)
	Total stock-based compensation expense	$	3,103		$	3,481
	Capitalized in oil and gas properties		(153	)		(123	)
	Net stock-based compensation expense	$	2,950		$	3,358

Property_and_Equipment_Schedul

Property and Equipment - Schedule of Total Property, Plant and Equipment, Net (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Capitalized Costs, Oil and Gas Producing Activities, Net [Abstract]
Proved properties	$5,518,122	$5,337,537
Unproved/unevaluated properties	521,842	550,979
Gathering systems and compressor stations	286,867	285,989
Other fixed assets	34,087	34,339
Total property and equipment, gross	6,360,918	6,208,844
Less: Accumulated depreciation, depletion and amortization, including impairment	-3,332,570	-2,434,003
Total property and equipment, net	$3,028,348	$3,774,841

Property_and_Equipment_Additio

Property and Equipment - Additional Information (Detail) (USD $)	3 Months Ended		12 Months Ended	0 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014	Dec. 30, 2013
				acre
				Well
Property, Plant and Equipment [Line Items]
Capitalized internal expense	$2.10	$1.60
Oil and natural gas properties excluded from amortization, full cost method	521.8		551
Pre-tax write-down of assets	798.1
Adjusted For Basis And Quality Differentials [Member]
Property, Plant and Equipment [Line Items]
West Texas Intermediate oil price (per Bbl)	79.21
Henry Hub natural gas price (per MMBtu)	3.88
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				$83.80
Acquisition date	28-Feb-14
Acquisition effective date	1-Dec-13

Commodity_Derivative_Contracts2

Commodity Derivative Contracts - Schedule of Derivative Instruments (Detail)	3 Months Ended
	Mar. 31, 2015
	bbl
Crude Oil [Member]
Derivative [Line Items]
Total Notional Volume	7,635,001
NGL-Product [Member]
Derivative [Line Items]
Total Notional Volume	1,924,999
Natural Gas [Member]
Derivative [Line Items]
Total Notional Volume MMBtu	53,120,000
Costless Collar [Member] | 2015 Settlement Period [Member] | Crude Oil [Member]
Derivative [Line Items]
Notional Daily Volume	7,778
Total Notional Volume	2,139,001
Average Floor/Fixed Prices	55
Average Ceiling/Fixed Prices	84.79
Costless Collar [Member] | 2015 Settlement Period [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional Daily Volume MMBtu	50,000
Total Notional Volume MMBtu	13,750,000
Average Floor/Fixed Prices	3.6
Average Ceiling/Fixed Prices	5.04
Costless Collar [Member] | 2016 Settlement Period [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional Daily Volume MMBtu	40,000
Total Notional Volume MMBtu	14,640,000
Average Floor/Fixed Prices	3.5
Average Ceiling/Fixed Prices	5.58
Swap [Member] | 2015 Settlement Period [Member] | Crude Oil [Member]
Derivative [Line Items]
Notional Daily Volume	12,000
Total Notional Volume	3,300,000
Average Floor/Fixed Prices	89.81
Swap [Member] | 2015 Settlement Period [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional Daily Volume MMBtu	50,000
Total Notional Volume MMBtu	13,750,000
Average Floor/Fixed Prices	4.13
Swap [Member] | 2015 Settlement Period [Member] | NGL-Ethane [Member]
Derivative [Line Items]
Notional Daily Volume	3,476
Total Notional Volume	955,952
Average Floor/Fixed Prices	11.31
Swap [Member] | 2015 Settlement Period [Member] | NGL-Propane [Member]
Derivative [Line Items]
Notional Daily Volume	1,750
Total Notional Volume	481,250
Average Floor/Fixed Prices	43.35
Swap [Member] | 2015 Settlement Period [Member] | NGL-Isobutane [Member]
Derivative [Line Items]
Notional Daily Volume	617
Total Notional Volume	169,583
Average Floor/Fixed Prices	53.05
Swap [Member] | 2015 Settlement Period [Member] | NGL-Normal Butane [Member]
Derivative [Line Items]
Notional Daily Volume	579
Total Notional Volume	159,107
Average Floor/Fixed Prices	52.53
Swap [Member] | 2015 Settlement Period [Member] | NGL-Pentanes Plus [Member]
Derivative [Line Items]
Notional Daily Volume	579
Total Notional Volume	159,107
Average Floor/Fixed Prices	77.72
Swap [Member] | 2016 Settlement Period [Member] | Crude Oil [Member]
Derivative [Line Items]
Notional Daily Volume	6,000
Total Notional Volume	2,196,000
Average Floor/Fixed Prices	90.28
Swap [Member] | 2016 Settlement Period [Member] | Natural Gas [Member]
Derivative [Line Items]
Notional Daily Volume MMBtu	30,000
Total Notional Volume MMBtu	10,980,000
Average Floor/Fixed Prices	4.04

Commodity_Derivative_Contracts3

Commodity Derivative Contracts - Schedule of Derivative Instruments in Statement of Financial Position (Detail) (Commodity Contracts [Member], Derivatives Not Designated As Hedging Instruments [Member], USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Derivatives Fair Value [Line Items]
Fair value of derivative instruments	$271,969	$286,669
Current Assets [Member] | Crude Oil [Member]
Derivatives Fair Value [Line Items]
Fair value of derivative instruments	146,443	151,363
Current Assets [Member] | NGL [Member]
Derivatives Fair Value [Line Items]
Fair value of derivative instruments	26,889	35,992
Current Assets [Member] | Natural Gas [Member]
Derivatives Fair Value [Line Items]
Fair value of derivative instruments	36,992	33,895
Non-Current Assets [Member] | Crude Oil [Member]
Derivatives Fair Value [Line Items]
Fair value of derivative instruments	47,863	54,187
Non-Current Assets [Member] | Natural Gas [Member]
Derivatives Fair Value [Line Items]
Fair value of derivative instruments	$13,782	$11,232

Commodity_Derivative_Contracts4

Commodity Derivative Contracts - Schedule of Derivative Gains and Losses Included in Derivative Instrument in Consolidated Statement of Operations (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Realized gain (loss) recognized in income	$62,203	($7,937)
Unrealized loss recognized in income	-14,700	-15,848
Total commodity derivative gain (loss) recognized in income	$47,503	($23,785)

Fair_Value_Measurements_Schedu

Fair Value Measurements - Schedule of Fair Value Assets and Liabilities Measured on Recurring Basis (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
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	$271,969	$286,669
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	271,969	286,669
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	-757	-3,209
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	757	3,209
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	271,969	286,669
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	272,726	289,878
Fair value of assets and liabilities measured on recurring basis	-757	-3,209
Netting [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	-757	-3,209
Fair value of assets and liabilities measured on recurring basis	$757	$3,209

Fair_Value_Measurements_Schedu1

Fair Value Measurements - Schedule of Valuation Process and Unobservable Inputs (Detail) (Level 3 [Member], USD $)	Mar. 31, 2015
In Thousands, unless otherwise specified
Derivative assets, Valuation Technique
Fair Value, Derivative Asset (Liability)	$271,969
Bbl [Member] | Derivative Assets [Member] | Crude Oil [Member] | Swap [Member]
Derivative assets, Valuation Technique
Fair Value, Derivative Asset (Liability)	185,817
Bbl [Member] | Derivative Assets [Member] | Crude Oil [Member] | Costless Collar [Member]
Derivative assets, Valuation Technique
Fair Value, Derivative Asset (Liability)	8,489
Bbl [Member] | Derivative Assets [Member] | Minimum [Member] | Crude Oil [Member] | Swap [Member]
Derivative assets, Valuation Technique
Forward Price Curve	48.18
Bbl [Member] | Derivative Assets [Member] | Minimum [Member] | Crude Oil [Member] | Costless Collar [Member]
Derivative assets, Valuation Technique
Forward Price Curve	-0.41
Bbl [Member] | Derivative Assets [Member] | Maximum [Member] | Crude Oil [Member] | Swap [Member]
Derivative assets, Valuation Technique
Forward Price Curve	62.53
Bbl [Member] | Derivative Assets [Member] | Maximum [Member] | Crude Oil [Member] | Costless Collar [Member]
Derivative assets, Valuation Technique
Forward Price Curve	5.16
Bbl [Member] | Derivative Assets [Member] | Weighted Average [Member] | Crude Oil [Member] | Swap [Member]
Derivative assets, Valuation Technique
Forward Price Curve	55.99
Bbl [Member] | Derivative Assets [Member] | Weighted Average [Member] | Crude Oil [Member] | Costless Collar [Member]
Derivative assets, Valuation Technique
Forward Price Curve	3.97
MMBtu [Member] | Derivative Assets [Member] | NGL [Member] | Swap [Member]
Derivative assets, Valuation Technique
Fair Value, Derivative Asset (Liability)	26,889
MMBtu [Member] | Derivative Assets [Member] | Natural Gas Swaps [Member] | Costless Collar [Member]
Derivative assets, Valuation Technique
Fair Value, Derivative Asset (Liability)	21,314
MMBtu [Member] | Derivative Assets [Member] | Natural Gas Swaps [Member] | Natural Gas Swaps [Member]
Derivative assets, Valuation Technique
Fair Value, Derivative Asset (Liability)	$29,460
MMBtu [Member] | Derivative Assets [Member] | Minimum [Member] | NGL [Member] | Swap [Member]
Derivative assets, Valuation Technique
Forward Price Curve	0.17
MMBtu [Member] | Derivative Assets [Member] | Minimum [Member] | Natural Gas Swaps [Member] | Costless Collar [Member]
Derivative assets, Valuation Technique
Forward Price Curve	-0.07
MMBtu [Member] | Derivative Assets [Member] | Minimum [Member] | Natural Gas Swaps [Member] | Natural Gas Swaps [Member]
Derivative assets, Valuation Technique
Forward Price Curve	-0.1
MMBtu [Member] | Derivative Assets [Member] | Maximum [Member] | NGL [Member] | Swap [Member]
Derivative assets, Valuation Technique
Forward Price Curve	1.17
MMBtu [Member] | Derivative Assets [Member] | Maximum [Member] | Natural Gas Swaps [Member] | Costless Collar [Member]
Derivative assets, Valuation Technique
Forward Price Curve	1.27
MMBtu [Member] | Derivative Assets [Member] | Maximum [Member] | Natural Gas Swaps [Member] | Natural Gas Swaps [Member]
Derivative assets, Valuation Technique
Forward Price Curve	3.36
MMBtu [Member] | Derivative Assets [Member] | Weighted Average [Member] | NGL [Member] | Swap [Member]
Derivative assets, Valuation Technique
Forward Price Curve	0.43
MMBtu [Member] | Derivative Assets [Member] | Weighted Average [Member] | Natural Gas Swaps [Member] | Costless Collar [Member]
Derivative assets, Valuation Technique
Forward Price Curve	0.75
MMBtu [Member] | Derivative Assets [Member] | Weighted Average [Member] | Natural Gas Swaps [Member] | Natural Gas Swaps [Member]
Derivative assets, Valuation Technique
Forward Price Curve	2.9

Fair_Value_Measurements_Additi

Fair Value Measurements - Additional Information (Detail) (USD $)	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Fair value of derivative instruments	$600,000
Fair market value of total debt	1,740,000,000
Carrying amount of debt	$1,840,000,000

Fair_Value_Measurements_Schedu2

Fair Value Measurements - Schedule of Fair Value Assets and Liabilities Classified (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Fair Value Disclosures [Abstract]
Derivative Asset (Liability) Balance, Beginning	$286,669	$4,419
Derivative Asset (Liability) Included in Earnings	47,503	-23,785
Derivative Asset (Liability) Settlements	-62,203	7,937
Derivative Asset (Liability) Transfers in and out of Level 3	0	0
Derivative Asset (Liability) Balance, Ending	$271,969	($11,429)

Asset_Retirement_Obligations_S

Asset Retirement Obligations - Schedule of Asset Retirement Obligations (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
ARO at the beginning of the period	$19,957
Liabilities incurred during period	62
Liabilities settled during period	-328
Accretion expense	323
ARO at the end of the period	$20,014

Asset_Retirement_Obligations_A

Asset Retirement Obligations - Additional Information (Detail) (USD $)	Mar. 31, 2015
In Millions, unless otherwise specified
Asset Retirement Obligation Disclosure [Abstract]
Current portion of ARO	$0.20
Long-term portion of ARO	$19.80

Debt_and_Credit_Agreements_Add

Debt and Credit Agreements - Additional Information (Detail) (USD $)	3 Months Ended	0 Months Ended
	Mar. 31, 2015	5-May-14	Dec. 31, 2014	Apr. 21, 2015	2-May-13	Nov. 15, 2013	29-May-14
Line of Credit Facility [Line Items]
Credit Facility, expiration date	30-Apr-18
Weighted average borrowing rate under Restated Revolver	1.96%
Pre-tax SEC PV-10 reserve value, percentage	80.00%
Pledge of membership and limited partnership interests percentage	100.00%
Current ratio	2.80%
Senior secured leverage ratio	0.10%
Interest coverage ratio	6.00%
Total outstanding borrowings	$1,840,000,000		$2,000,000,000
Weighted average borrowing rate	5.55%
Subsequent Event [Member]
Line of Credit Facility [Line Items]
Current borrowing base				950,000,000
Borrowing base increased				800,000,000
5.625% Senior Notes due 2021 [Member]
Line of Credit Facility [Line Items]
Debt instrument, interest rate, stated percentage					5.63%
Debt maturity date	Senior Notes due 2021
Issuance of aggregate principal amount					700,000,000
5.875% Senior Notes due 2022 [Member]
Line of Credit Facility [Line Items]
Debt instrument, interest rate, stated percentage						5.88%
Debt maturity date	Senior Notes due 2022
Issuance of aggregate principal amount						600,000,000
5.875% Senior Notes due 2024 [Member]
Line of Credit Facility [Line Items]
Debt instrument, interest rate, stated percentage							5.88%
Debt maturity date	Senior Notes due 2024
Issuance of aggregate principal amount							500,000,000
9.500% Senior Notes due 2018 [Member]
Line of Credit Facility [Line Items]
Debt instrument, interest rate, stated percentage		9.50%
Debt maturity date	Senior Notes due 2018
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
9.500% Senior Notes due 2018 [Member] | Accounts Payable and Accrued Liabilities [Member]
Line of Credit Facility [Line Items]
Accrued and unpaid interest		1,100,000
Minimum [Member]
Line of Credit Facility [Line Items]
Current ratio	1.00%
London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt instrument, interest rate, stated percentage	2.50%
Alternative Base Rate [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt instrument, interest rate, stated percentage	0.50%
Alternative Base Rate [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt instrument, interest rate, stated percentage	1.50%
Amended and Restated Senior Revolving Credit Agreement [Member]
Line of Credit Facility [Line Items]
Amount outstanding	40,000,000
Available borrowing capacity	760,000,000
Amended and Restated Senior Revolving Credit Agreement [Member] | London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt instrument, interest rate, stated percentage	1.50%
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Interest expense on Credit Facility	900,000
Commitment fees on Credit Facility	$600,000

Income_Taxes_Additional_Inform

Income Taxes - Additional Information (Detail) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Effective tax rate	35.30%	35.20%
Unrecognized tax benefits	$0		$0
Deferred tax liability	12,800,000
Valuation allowance	$0

Commitments_and_Contingencies_1

Commitments and Contingencies - Additional Information (Detail) (USD $)	3 Months Ended
	Mar. 31, 2015
	Drilling_Rig
Oil and Gas Delivery Commitments and Contracts [Line Items]
Accrued deficiency fees	$4,900,000
Number of outstanding drilling rig commitments	0
Outstanding commitments	7,000,000
Minimum remaining contractual commitment for other field services	5,200,000
Rig termination fees	15,800,000
Reserve for commercial disputes	9,200,000
Total reserve related to dispute	$15,000,000
Oil Commitments (MMBbls) [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Oil and gas delivery transportation commitments	4.1
Natural Gas Commitments (MMBtus) [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Oil and gas delivery transportation commitments	575,000,000

Commitments_and_Contingencies_2

Commitments and Contingencies - Future Obligations Under Firm Gas and Oil Transportation Agreements (Detail) (USD $)	Mar. 31, 2015
In Thousands, unless otherwise specified
Oil and Gas Delivery Commitments and Contracts Additional Information [Abstract]
2015	$16,664
2016	22,132
2017	21,708
2018	18,159
2019	15,900
Thereafter	86,507
Total future obligations	$181,070

Equity_Schedule_of_Basic_and_D

Equity - Schedule of Basic and Diluted Weighted Average Shares Outstanding (Detail)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Earnings Per Share [Abstract]
Basic weighted average number of shares outstanding	64,082	61,380
Dilution effect of stock options and restricted shares at the end of the period		167
Diluted weighted average number of shares outstanding	64,082	61,547
Anti-dilutive stock awards and shares	566	9

Equity_Additional_Information_

Equity - Additional Information (Detail) (USD $)	3 Months Ended	0 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2015	Apr. 08, 2015
Equity [Line Items]
Common stock price per share	$17.20
Selling price per share net of underwriting discount	$17.04
Net proceeds from equity issue	$204,415
Underwriters Over-Allotment Option [Member] | Subsequent Event [Member]
Equity [Line Items]
Public offering of common stock		1,800,000
Common Stock [Member]
Equity [Line Items]
Public offering of common stock	12,000,000
Net proceeds from equity issue	204,500
Common Stock [Member] | Underwriters Over-Allotment Option [Member] | Subsequent Event [Member]
Equity [Line Items]
Net proceeds from equity issue		30,700

StockBased_Compensation_and_Em2

Stock-Based Compensation and Employee Benefits - Schedule of Stock-Based Compensation Expense (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Total stock-based compensation expense	$3,103	$3,481
Capitalized in oil and gas properties	-153	-123
Net stock-based compensation expense	$2,950	$3,358

StockBased_Compensation_and_Em3

Stock-Based Compensation and Employee Benefits - Additional Information (Detail) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$2,950,000	$3,358,000
Stock-based compensation expense associated with PSUs	3,103,000	3,481,000
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2,900,000
Unrecognized stock-based compensation expense	21,200,000
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized stock-based compensation expense	13,000,000
PSUs performance period, in years	3 years
Stock-based compensation expense associated with PSUs	$200,000
Number of shares vested range, percentage of targeted amounts	200.00%

Guarantor_Subsidiaries_Additio

Guarantor Subsidiaries - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2015
Guarantees [Abstract]
Number of subsidiaries with restricted assets that exceed 25% of net assets	none
Maximum percentage of non-transferrable net assets	25.00%