RSP Permian (RSPP) 10-Q 14 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document	6 Months Ended
	Jun. 30, 2014	Aug. 12, 2014
Document and Entity Information [Abstract]	'	'
Entity Registrant Name	'RSP Permian, Inc.	'
Entity Central Index Key	'0001588216	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Non-accelerated Filer	'
Document Type	'10-Q	'
Document Period End Date	30-Jun-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'
Amendment Flag	'false	'
Entity Common Stock, Shares Outstanding	'	77,291,667

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
CURRENT ASSETS	'	'
Cash and cash equivalents	$14,733	$13,234
Accounts receivable	32,281	26,346
Accounts receivable, related party	1,107	3,672
Escrow receivable	0	3,197
Escrow deposit	17	15
Derivative instruments	1,629	671
Total current assets	49,767	47,135
PROPERTY, PLANT AND EQUIPMENT	'	'
Oil and natural gas properties, successful efforts method	1,666,007	595,486
Accumulated depletion	-117,415	-88,514
Total oil and natural gas properties, net	1,548,592	506,972
Other property and equipment, net	14,345	9,316
Total property, plant and equipment	1,562,937	516,288
LONG-TERM ASSETS	'	'
Derivative instruments	2,101	1,078
Restricted cash	150	150
Other assets	17,975	23,004
Total long-term assets	20,226	24,232
TOTAL ASSETS	1,632,930	587,655
CURRENT LIABILITIES	'	'
Accounts payable	28,413	18,548
Accrued expenses	21,065	10,460
Interest payable	337	296
Derivative instruments	16,411	1,562
Total current liabilities	66,226	30,866
LONG-TERM LIABILITIES	'	'
Asset retirement obligations	4,992	2,584
Derivative instruments	5,458	43
Term loan	0	70,000
Revolving credit facility	140,000	58,155
NPI payable	0	36,931
Deferred taxes	336,458	2,195
Total long-term liabilities	486,908	169,908
Total liabilities	553,134	200,774
STOCKHOLDERS’/MEMBERS’ EQUITY	'	'
Members’ equity	'	386,881
Common stock, $.01 par value; 300,000,000 shares authorized, 72,500,000 shares issued and outstanding at June 30, 2014; no shares authorized, issued or outstanding at December 31, 2013	725	'
Additional paid-in capital	1,198,374	'
Accumulated deficit	-119,303	'
Total stockholders’/members’ equity	1,079,796	386,881
TOTAL LIABILITIES AND STOCKHOLDERS’/MEMBERS’ EQUITY	$1,632,930	$587,655

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Common stock, par value (in dollars per share)	$0.01	'
Common stock, shares authorized	300,000,000	0
Common stock, shares issued	72,500,000	0
Common stock, shares outstanding	72,500,000	0

Consolidated_Statement_of_Oper

Consolidated Statement of Operations (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	$66,134	$22,442	$117,606	$44,365
Natural gas sales	3,117	1,397	5,323	2,562
NGL sales	4,811	1,309	8,892	2,876
Total revenues	74,062	25,148	131,821	49,803
OPERATING EXPENSES	'	'	'	'
Lease operating expenses	9,279	2,853	16,342	6,208
Production and ad valorem taxes	5,964	1,874	9,840	3,510
Depreciation, depletion and amortization	21,734	12,032	38,096	22,234
Asset retirement obligation accretion	38	26	66	51
Exploration	1,233	94	1,989	157
General and administrative expenses	5,238	1,069	22,254	1,624
Total operating expenses	43,486	17,948	88,587	33,784
(Gain) loss on sale of assets	0	84	0	-6,045
OPERATING INCOME	30,576	7,116	43,234	22,064
OTHER INCOME (EXPENSE)	'	'	'	'
Other income (expense)	-302	366	8	565
Gain (loss) on derivative instruments	-15,958	922	-20,111	-735
Interest expense	-1,142	-477	-2,272	-1,101
Total other income (expense)	-17,402	811	-22,375	-1,271
INCOME BEFORE TAXES	13,174	7,927	20,859	20,793
INCOME TAX EXPENSE	-4,948	-68	-140,162	-68
NET INCOME (LOSS)	$8,226	$7,859	($119,303)	$20,725
Income (loss) per common share:	'	'	'	'
Basic (in dollars per share)	$0.11	'	($1.76)	'
Diluted (in dollars per share)	$0.11	'	($1.76)	'
Weighted average shares outstanding:	'	'	'	'
Weighted average number of common shares outstanding - basic	72,500	'	67,702	'
Weighted average number of common shares outstanding - diluted (2)	72,500	'	67,702	'

Consolidated_Statement_of_Chan

Consolidated Statement of Changes In Shareholders'/Members' Equity (USD $)	Total	Members' Equity [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Accumulated Deficit [Member]
In Thousands, except Share data, unless otherwise specified
Total Stockholders' Equity/Members' Equity, beginning balance at Dec. 31, 2013	$386,881	$386,881	$0	$0	$0
Issued Shares of Common Stock, beginning balance at Dec. 31, 2013	0	'	0	'	'
Stockholders' Equity/Members' Equity [Roll Forward]	'	'	'	'	'
Distribution of net assets to predecessor owner, including cash of $1,663	-6,979	-21,147	'	14,168	'
The corporate reorganization	'	-365,734	'	365,734	'
RSP Permian Holdco, L.L.C.’s contributions of interests in RSP Permian, L.L.C. in exchange for RSP Permian, Inc.’s common stock, Shares	'	'	63,275,000	'	'
RSP Permian Holdco, L.L.C.’s contributions of interests in RSP Permian, L.L.C. in exchange for RSP Permian, Inc.’s common stock, Value	'	'	633	-633	'
Ted Collins, Jr., Wallace Family Partnership, LP, Collins & Wallace Holdings, LLC, Pecos Energy Partners, L.P. and ACTOIL LLC’s contributions in exchange for RSP Permian, Inc.’s common stock	642,436	'	'	642,436	'
Shares of common stock sold in initial public offering net of offering costs, Shares	'	'	9,225,000	'	'
Shares of common stock sold in initial public offering net of offering costs, Value	163,082	'	92	162,990	'
Equity-based compensation	13,679	'	'	13,679	'
Net loss	-119,303	'	'	'	-119,303
Total Stockholders' Equity/Members' Equity, ending balance at Jun. 30, 2014	$1,079,796	$0	$725	$1,198,374	($119,303)
Issued Shares of Common Stock, ending balance at Jun. 30, 2014	72,500,000	'	72,500,000	'	'

Consolidated_Statement_of_Chan1

Consolidated Statement of Changes In Shareholders'/Members' Equity (Parenthetical) (Members' Equity [Member], USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014
Members' Equity [Member]	'
Cash distribution paid to predecessor owner	$1,663

Consolidated_Statement_of_Cash

Consolidated Statement of Cash Flows (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
CASH FLOWS FROM OPERATING ACTIVITIES	'	'
Net income (loss)	($119,303)	$20,725
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	38,096	21,972
Abandoned equipment and intangibles	0	2
Accretion of asset retirement obligations	66	51
Equity based compensation	13,679	0
Amortization of loan fees	423	262
Deferred income taxes	138,486	0
Equity in earnings of investment	0	-13
(Gain) on sale of assets	0	-6,045
Loss on derivative instruments	20,111	735
Net cash payments on settled derivatives	-1,828	-328
Changes in operating assets and liabilities:	'	'
Accounts receivable and accounts receivable from related parties	-3,371	9,249
Other assets	4,838	-2,673
Interest payable	41	-91
Accounts payable	9,865	-12,921
Accrued expenses	-4,010	491
Net cash provided by operating activities	97,093	31,416
CASH FLOWS FROM INVESTING ACTIVITIES	'	'
Proceeds from sale of assets	0	115,339
Additions to other property and equipment	-1,740	82
Additions to oil and natural gas properties	-268,886	-88,187
Net cash provided by (used in) investing activities	-270,626	27,234
CASH FLOWS FROM FINANCING ACTIVITIES	'	'
Issuance of common stock	163,082	0
Distributions	-1,663	-29,700
Payment of deferred loan costs	-232	0
Borrowings under long-term debt	140,000	500
Payments on long-term debt	-126,155	-85,000
NPI payable	0	20,349
Net cash provided by (used in) financing activities	175,032	-93,851
NET CHANGE IN CASH	1,499	-35,201
CASH AT BEGINNING OF PERIOD	13,234	51,232
CASH AT END OF PERIOD	14,733	16,031
SUPPLEMENTAL CASH FLOW INFORMATION	'	'
Cash paid for interest	1,808	624
Cash paid for taxes	1,800	0
NON-CASH ACTIVITIES	'	'
Asset retirement obligation acquired	2,412	0
Common stock issued for oil and gas properties	677,402	0
Deferred tax liabilities recorded for oil and gas property acquisitions	195,777	0
Elimination of NPI payable	$36,931	$0

Nature_of_Operations_and_Basis

Nature of Operations and Basis of Presentation	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Nature of Operations and Basis of Presentation	'
	NATURE OF OPERATIONS AND BASIS OF PRESENTATION
	Organization and Description of the Business
	RSP Permian, Inc. ("RSP Inc." or "the Company") was formed on September 30, 2013, pursuant to the laws of the state of Delaware as a holding company for RSP Permian, L.L.C., a Delaware limited liability company (“RSP LLC”). RSP LLC was formed on October 18, 2010 by its management team and an affiliate of Natural Gas Partners, a family of energy-focused private equity investment funds (“NGP”). The Company is engaged in the acquisition, development and operation of oil and natural gas properties. Additional background on and details of the ownership of the Company and RSP LLC are available in the Company's Annual Report on Form 10-K for the year ended December 31, 2013.
	On January 23, 2014, RSP Inc. completed an initial public offering (the “IPO”) and on January 17, 2014, shares of RSP Inc. began trading on the New York Stock Exchange under the ticker “RSPP.” In the IPO, 23 million shares were sold at $19.50 per share, raising $449 million of gross proceeds. Of the 23 million shares, 9.2 million were shares sold by RSP Inc., resulting in approximately $163 million of net proceeds, which were used to fully repay the Company’s $70 million term loan, repay outstanding borrowings of $56 million under its revolving credit facility, make cash payments to certain existing investors as partial consideration for the properties contributed to the Company by such persons, pay cash bonuses to certain of the Company’s employees in connection with the successful completion of the IPO, and fund a portion of its capital expenditure plan. The remaining 13.8 million shares sold in the IPO were sold by selling stockholders, and the Company did not receive any proceeds from the sale of those shares.
	In connection with the IPO, several transactions occurred that changed the structure and scope of the Company:
	• Corporate Reorganization: RSP LLC was contributed to RSP Permian Holdco, L.L.C., a newly formed limited liability company, which contributed all of its interests in RSP LLC to RSP Inc. in exchange for shares of RSP Inc.’s common stock, an assignment of RSP LLC’s pro rata share of an escrow related to the Resolute Sale (as defined and described in Note 3) and cash. As a result of this reorganization, RSP LLC became a wholly owned subsidiary of RSP Inc.
	•The Rising Star Acquisition: RSP Inc. acquired from Rising Star Energy Development Co., L.L.C., a Texas limited liability company (“Rising Star”), working interests in certain acreage and wells in the Permian Basin in which RSP LLC already had working interests in exchange for shares of RSP Inc.’s common stock and cash.
	•The Collins and Wallace Contributions: Ted Collins, Jr. (“Collins”), Wallace Family Partnership, LP (“Wallace LP”) and Collins & Wallace Holdings, LLC, a newly formed entity that is jointly owned by Collins and Wallace LP, contributed certain working interests in the Permian Basin in which RSP LLC already had working interests in exchange for shares of RSP Inc.’s common stock and, in the case of Collins and Wallace LP, cash (such contributions, the “Collins and Wallace Contributions”). See Note 3 for additional information.
	•The Pecos Contribution: Pecos Energy Partners, L.P. (“Pecos”), an entity owned by certain members of the Company’s management team, contributed certain working interests in acreage and wells in the Permian Basin in which RSP LLC already had a working interest in exchange for shares of RSP Inc.’s common stock.
	•The ACTOIL NPI Repurchase:  ACTOIL, LLC (“ACTOIL”), the owner of a 25% net profits interest (“NPI”) in substantially all of RSP LLC’s oil and natural gas properties taken as a whole, contributed their 25% NPI in exchange for shares of RSP Inc.’s common stock (such contribution, the “ACTOIL NPI Repurchase”).  See Note 3 for more information.
	Basis of Presentation
	These financial statements have been prepared by the Company pursuant to the rules and regulations of the SEC. They reflect all adjustments that are, in the opinion of management, necessary for a fair statement of the results for interim periods, on a basis consistent with the audited annual financial statements. All such adjustments are of a normal recurring nature. Certain information, accounting policies and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) have been omitted pursuant to such rules and regulations, although the Company believes the disclosures are adequate to make the information presented not misleading. These financial statements should be read together with the financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013.
	Subsequent Events
	The Company has evaluated subsequent events of its consolidated financial statements. As discussed in Note 3, in July 2014 the Company entered into multiple agreements to acquire predominantly undeveloped acreage and certain oil and gas producing properties located in Glasscock County, Texas, for an approximate aggregate price of $259 million. These acquisitions are expected to close in late August 2014. Also in July 2014, the Company filed an amended registration statement on Form S-1 with the SEC, and in August 2014 completed an underwritten public offering of 11.5 million shares of common stock. In the offering, selling shareholders sold 6.7 million shares and the Company sold 4.8 million shares. The stock was sold to the public at $25.65 per share and the Company received net proceeds of approximately $117.8 million, net of offering expenses and underwriting discounts and commissions. We used the proceeds from this stock sale to repay amounts drawn under our revolving credit facility and for general corporate purposes. We may at any time re-borrow amounts under our revolving credit facility, and we expect to do so to fund a portion of the pending Glasscock County acquisitions. There were no other material subsequent events requiring additional disclosure in these financial statements.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	Use of Estimates
	The preparation of the consolidated financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities in the financial statements and accompanying notes. Although management believes these estimates are reasonable, actual results could differ from these estimates. Changes in estimates are recorded prospectively. Significant assumptions are required in the valuation of proved oil and natural gas reserves that may affect the amount at which oil and natural gas properties are recorded. Estimation of asset retirement obligations (“AROs”) and valuations of derivative instruments and the fair value of incentive unit compensation also require significant assumptions. It is possible that these estimates could be revised at future dates and these revisions could be material. Depletion of oil and natural gas properties are determined using estimates of proved oil and natural gas reserves. There are numerous uncertainties inherent in the estimation of quantities of proved reserves and in the projection of future rates of production and the timing of development expenditures. Similarly, evaluations for impairment of proved and unproved oil and natural gas properties are subject to numerous uncertainties including, among others, estimates of future recoverable reserves and commodity price estimates.
	Reclassifications
	Certain reclassifications have been made to prior periods to conform to current period presentation.
	Accounts Receivable from Related Parties
	The Company’s accounts receivable from related parties as of June 30, 2014 was $1.1 million and was owed by Collins, Wallace LP, Collins & Wallace Holdings, LLC, and Pecos. The balance as of December 31, 2013 was $3.7 million and was owed by Wallace LP.
	Prior to the IPO, Collins, Wallace LP and Collins & Wallace Holdings, LLC had non-operated working interests in substantially all of the oil and natural gas assets that the Company operates. The Company considers the accounts receivable from these related parties to be fully collectible.
	Oil and Natural Gas Properties
	The Company uses the successful efforts method of accounting for its oil and natural gas exploration and production activities. Costs incurred by the Company related to the acquisition of oil and natural gas properties and the cost of drilling development wells and successful exploratory wells are capitalized, while the costs of unsuccessful exploratory wells are expensed when determined to be unsuccessful.
	The Company capitalizes interest on expenditures while activities are in progress to bring the assets to their intended use for significant exploration and development projects that last more than six months. The Company did not capitalize any interest in the six months ended June 30, 2014 and 2013 as no projects lasted more than six months. Costs incurred to maintain wells and related equipment, lease and well operating costs and other exploration costs are expensed as incurred. Gains and losses arising from the sale of properties are generally included in operating income. Unproved properties are assessed periodically for possible impairment.
	Capitalized acquisition costs attributable to proved oil and natural gas properties and leasehold costs are depleted on a field basis based on proved reserves using the unit-of-production method. Capitalized exploration well costs and development costs, including AROs, are depleted on a field basis, based on proved developed reserves. For the three months ended June 30, 2014 and 2013, depletion expense for oil and natural gas producing property was $21.6 million and $11.5 million, respectively. For the six months ended June 30, 2014 and 2013, depletion expense for oil and natural gas producing property was $37.9 million and $21.7 million, respectively. Depletion expense is included in depreciation, depletion and amortization in the accompanying consolidated statements of operations.
	The Company’s oil and natural gas properties as of June 30, 2014 and December 31, 2013 consisted of the following:
			June 30, 2014			December 31, 2013
			(In thousands)
	Proved oil and natural gas properties		$	1,157,129		$	562,019
	Unproved oil and natural gas properties		508,878			33,467
	Total oil and natural gas properties		1,666,007			595,486
	Less: accumulated depletion		(117,415		)	(88,514		)
	Total oil and natural gas properties, net		$	1,548,592		$	506,972
	In some circumstances, it may be uncertain whether proved commercial reserves have been found when drilling has been completed. Such exploratory well drilling costs may continue to be capitalized if the anticipated reserve quantity is sufficient to justify its completion as a producing well and sufficient progress in assessing the reserves and the economic and operating viability of the project is being made. As of June 30, 2014 and December 31, 2013, there were no costs capitalized in connection with exploratory wells in progress.
	Capitalized costs are evaluated for impairment whenever events or changes in circumstances indicate that an asset’s carrying amount may not be recoverable. To determine if a depletable unit (field) is impaired, the Company compares the carrying value of the depletable unit to the undiscounted future net cash flows by applying estimates of future oil and natural gas prices to the estimated future production of oil and natural gas reserves over the economic life of the property and deducting future costs. Future net cash flows are based upon reservoir engineers’ estimates of proved reserves.
	For a property determined to be impaired, an impairment loss equal to the difference between the property’s carrying value and estimated fair value is recognized. Fair value, on a field basis, is estimated to be the present value of the aforementioned expected future net cash flows. Unproved properties are assessed periodically to determine whether they have been impaired. An impairment allowance is provided on an unproved property when the Company determines that the property will not be developed. Each part of this calculation is subject to a large degree of judgment, including the determination of the depletable units’ estimated reserves, future net cash flows and fair value.  No impairment of proved property was recorded for the three or six months ended June 30, 2014 or 2013.
	Natural gas volumes are converted to Boe at the rate of six Mcf of natural gas to one Bbl of oil. This convention is not an equivalent price basis and there may be a large difference in value between an equivalent volume of oil versus an equivalent volume of natural gas. NGL volumes are stated in barrels.
	Asset Retirement Obligation
	The Company records AROs related to the retirement of long-lived assets at the time a legal obligation is incurred and the liability can be reasonably estimated. AROs are recorded as long-term liabilities with a corresponding increase in the carrying amount of the related long-lived asset. Subsequently, the asset retirement cost included in the carrying amount of the related asset is allocated to expense through depletion of the asset. Changes in the liability due to passage of time are generally recognized as an increase in the carrying amount of the liability and as corresponding accretion expense.
	The Company estimates a fair value of the obligation on each well in which it owns an interest by identifying costs associated with the future down-hole plugging, dismantlement and removal of production equipment and facilities, and the restoration and reclamation of a field’s surface to a condition similar to that existing before oil and natural gas extraction began.
	In general, the amount of ARO and the costs capitalized will be equal to the estimated future cost to satisfy the abandonment obligation using current prices that are escalated by an assumed inflation factor up to the estimated settlement date which is then discounted back to the date that the abandonment obligation was incurred using an estimated credit adjusted rate. If the estimated ARO changes, an adjustment is recorded to both the ARO and the long-lived asset. Revisions to estimated AROs can result from changes in retirement cost estimates, revisions to estimated inflation rates and changes in the estimated timing of abandonment.
	After recording these amounts, the ARO is accreted to its future estimated value using the same assumed credit adjusted rate and the associated capitalized costs are depreciated on a unit-of-production basis.
	The ARO consisted of the following for the period indicated:
		Six Months Ended
		June 30, 2014
		(In thousands)
	Asset retirement obligation at beginning of period	$	2,584
	Liabilities assumed	2,342
	Accretion expense	66
	Asset retirement obligation at end of period	$	4,992
	Income Taxes
	RSP LLC was organized as a limited liability company and treated as a flow-through entity for federal income tax purposes.  As such, taxable income and any related tax credits were passed through to its members and are included in their tax returns even though such net taxable income or tax credits may not have actually been distributed. Accordingly, provision for federal and state corporate income taxes has been made only for the operations of RSP Inc. from January 23, 2014 through June 30, 2014 in the accompanying consolidated financial statements. Deferred income taxes are provided to reflect the future tax consequences or benefits of differences between the tax basis of assets and liabilities and their reported amounts in the financial statements using enacted tax rates. Upon the conversion from a limited liability company to a corporation on January 23, 2014, the Company established a $132 million provision for deferred income taxes, which was recognized as tax expense from continuing operations.  The primary upward adjustments in the effective tax rate above the U.S. statutory rate are the adjustment related to converting from a limited liability company to a corporation noted above along with non-deductible incentive unit compensation.
	The following is an analysis of the Company’s consolidated income tax expense:
			Three Months Ended June 30,						Six Months Ended June 30,
			2014			2013			2014		2013
			(In thousands)						(In thousands)
	Current		$	805		$	68		$	1,676	$	68
	Deferred		4,143			—			138,486		—
	Income Tax Expense		$	4,948		$	68		$	140,162	$	68
	Deferred taxes are determined based on the estimated future tax effects of differences between the financial statement and tax basis of assets and liabilities, given the provisions of enacted tax laws. Tax positions are evaluated for recognition using a more-likely-than-not threshold, and those tax positions requiring recognition are measured as the largest amount of tax benefit that is greater than fifty percent likely of being realized upon ultimate settlement with a taxing authority that has full knowledge of all relevant information. The Company’s policy is to record interest and penalties relating to uncertain tax positions in income tax expense. At June 30, 2014, the Company did not have any accrued liability for uncertain tax positions and does not anticipate recognition of any significant liabilities for uncertain tax positions during the next 12 months.
	The Company’s U.S. federal income tax returns and Texas franchise tax returns for 2010 and beyond remain subject to examination by the taxing authorities. There are no material unresolved items related to periods previously audited by these taxing authorities. No other jurisdiction’s returns are significant to the Company’s financial position.
	New Accounting Pronouncements
	In May 2014, the Financial Accounting Standards Board ("FASB") issued ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” which provides a comprehensive revenue recognition standard for contracts with customers that supersedes current revenue recognition guidance including industry specific guidance. An entity is required to apply ASU 2014-09 for annual and interim reporting periods beginning after December 15, 2016. An entity can apply ASU 2014-09 using either a full retrospective method, meaning the standard is applied to all of the periods presented, or a modified retrospective method, meaning the cumulative effect of initially applying the standard is recognized in the most current period presented in the financial statements. The Company is evaluating the impact that this new guidance will have on its consolidated financial statements.

Acquisitions_and_Sales_of_Oil_

Acquisitions and Sales of Oil and Natural Gas Property Interests	6 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Acquisitions and Sales of Oil and Natural Gas Property Interests	'
	ACQUISITIONS AND SALES OF OIL AND NATURAL GAS PROPERTY INTERESTS
	Pro Forma Results
	The Company’s summary pro forma results for the three and six months ended June 30, 2013 were derived from the actual results of the Company’s accounting predecessor, which reflects the combined results of RSP LLC and Rising Star, and have been adjusted to reflect the Collins and Wallace Contributions and the ACTOIL NPI Repurchase, both of which were completed in connection with the IPO on January 23, 2014, as if such transactions had occurred on January 1, 2013. Additionally, the pro forma results for the 2013 periods include the estimated activity associated with the Spanish Trail Acquisition (as defined below), which was completed in September 2013, and the Resolute Sale, which was completed in March 2013, as if each of these transactions had occurred on January 1, 2013.
	Our pro forma results for the six months ended June 30, 2014 were derived from our actual results and have been adjusted to reflect the Collins and Wallace Contributions and the ACTOIL NPI Repurchase, both of which were completed in connection with the IPO on January 23, 2014, as if such transactions had occurred on January 1, 2013. There were no pro forma adjustments required for the three months ended June 30, 2014.
	The pro forma financial information included below does not give effect to certain acquisitions that were immaterial to our actual and pro forma results for the periods reflected below and does not make any adjustments for non-recurring expenses associated with the IPO.
	The unaudited pro forma financial information does not purport to be indicative of results of operations that would have occurred had the transaction occurred on the basis assumed above, nor is such information indicative of expected future results of operations.
			Three Months Ended June 30, 2014						Three Months Ended June 30, 2013
			Actual			Pro Forma			Actual		Pro Forma
			(In thousands)						(In thousands)
	Revenues		$	74,062		$	74,062		$	25,148	$	47,377
	Net income (loss)		$	8,226		$	8,226		$	7,859	$	17,190
			Six Months Ended June 30, 2014						Six Months Ended June 30, 2013
			Actual			Pro Forma			Actual		Pro Forma
			(In thousands)						(In thousands)
	Revenues		$	131,821		$	136,806		$	49,803	$	80,568
	Net income (loss)		$	(119,303	)	$	(119,059	)	$	20,725	$	25,136
	Recent Acquisitions
	During the first quarter of 2014, the Company acquired additional acreage prospective for horizontal development in Martin, Glasscock and Dawson counties for an aggregate purchase price of approximately $79 million in three separate transactions with approximately $69 million recorded as proved oil and natural gas properties. The transactions were financed with borrowings under the Company’s revolving credit facility.
	In July 2014, the Company entered into multiple agreements to acquire predominantly undeveloped acreage and certain oil and gas producing properties located in Glasscock County, Texas, for an approximate aggregate price of $259 million. These acquisitions are expected to close in late August 2014, and we expect to fund a portion of this acquisition through borrowings under our revolving credit facility.
	Collins and Wallace Contributions
	Collins, Wallace LP and Collins & Wallace Holdings, LLC contributed to RSP Inc. certain working interests in the Permian Basin in which RSP LLC already had working interests. In exchange, (i) Collins received shares of RSP Inc.’s common stock and the right to receive approximately $1.6 million in cash, (ii) Wallace LP received shares of RSP Inc.’s common stock and the right to receive $0.6 million in cash, and (iii) Collins & Wallace Holdings, LLC received shares of RSP Inc.’s common stock. The Collins and Wallace Contributions occurred in connection with the IPO.
	These contributed working interests consist of the following: (i) Collins’ non-operated working interest in substantially all of the oil and natural gas properties that RSP LLC owned prior to the Spanish Trail Acquisition; (ii) Wallace LP’s non-operated working interest in substantially all of the oil and natural gas properties that RSP LLC owned prior to the Spanish Trail Acquisition; and (iii) Collins & Wallace Holdings, LLC’s non-operated working interest in the Spanish Trail Assets (as defined below).
	A summary of the consideration transferred and the fair value of assets and liabilities acquired in connection with the Collins and Wallace Contributions is as follows (in thousands):
	Value of the 22,023,654 shares of the Company’s common stock issued in the Collins and Wallace Contributions	$	429,461
	Cash paid in the Collins and Wallace Contributions	2,219
	Total consideration for the assets contributed in the Collins and Wallace Contributions	$	431,680
	Fair value of oil and natural gas properties	$	644,052
	Asset retirement obligation	(1,063		)
	Deferred tax liability*	(211,309		)
	Total net assets acquired	$	431,680
	_______________________________________
	*       Amount represents the estimated book to tax difference in oil and natural gas properties as of the acquisition date on a tax-effected basis of approximately 35%.
	ACTOIL NPI Repurchase
	In July 2011, RSP LLC sold to ACTOIL a 25% NPI in substantially all of its oil and natural gas properties taken as a whole.  In addition, RSP LLC sold to ACTOIL a 25% NPI in the oil and natural gas properties acquired by RSP LLC in the Spanish Trail Acquisition. In connection with the IPO, ACTOIL contributed both 25% NPIs to the Company in exchange for shares of RSP Inc.’s common stock. The 25% NPIs exchanged for shares in the Company had a value of approximately $210.9 million and were accounted for as asset acquisitions.
	The Company’s predecessor’s sale of properties to Resolute Natural Resources Southwest LLC (“Resolute”) in December 2012 and March 2013 resulted in ACTOIL earning cash proceeds through its NPI in the properties sold.  ACTOIL reduced its NPI account cumulative deficit balance with these proceeds, rather than receiving a cash distribution.  As such, the Company’s predecessor applied the NPI proceeds dollar-for-dollar to reduce the NPI deficit balance and recorded the amount as a long-term NPI payable on its balance sheet.  This amount was eliminated upon ACTOIL contributing its NPI in exchange for common shares.
	A summary of the consideration transferred and the assets acquired and liabilities acquired in connection with the ACTOIL NPI Repurchase is as follows (in thousands):
	Value of the 10,816,626 shares of the Company’s common stock issued in the ACTOIL NPI Repurchase	$	210,924
	Elimination of NPI payable	(36,931		)
	Total consideration for the assets contributed in the ACTOIL NPI Repurchase	$	173,993
	Oil and natural gas properties cost	$	158,115
	Asset retirement obligation	(639		)
	Deferred tax asset*	16,517
	Total net assets acquired	$	173,993
	_______________________________________
	*       Amount represents the estimated book to tax difference in oil and natural gas properties as of the acquisition date on a tax-effected basis of approximately 35%.
	Spanish Trail Acquisition
	On September 10, 2013, RSP LLC acquired additional working interests in certain of its existing properties in the Permian Basin (the “Spanish Trail Acquisition”) from Summit Petroleum, LLC (“Summit”) and EGL Resources, Inc. (“EGL”).  The aggregate purchase price for the assets acquired in the Spanish Trail Acquisition (the “Spanish Trail Assets”) agreed to by RSP LLC and the sellers was $155 million.
	Subsequent to the signing of the purchase agreement and prior to the closing of the Spanish Trail Acquisition, Collins and Wallace LP, non-operating working interest owners in the Spanish Trail Assets, exercised preferential purchase rights granted under a joint operating agreement among the working interest owners in the Spanish Trail Assets. The preferential purchase rights gave Collins and Wallace LP the right to purchase a portion of the working interests sold by Summit and EGL. Collins and Wallace LP completed this acquisition through Collins & Wallace Holdings, LLC, a newly formed entity that is jointly owned by Collins and Wallace LP, which contributed these acquired assets to RSP Inc. in exchange for shares of RSP Inc.’s common stock in connection with the IPO. The exercise of the preferential purchase rights reduced RSP LLC’s purchase price from $155 million to $121 million.
	Simultaneously with the closing of the Spanish Trail Acquisition, pursuant to ACTOIL’s exercise of a right of first refusal granted by RSP LLC in the agreement that governs ACTOIL’s NPI investment, RSP LLC conveyed a 25% NPI in the Spanish Trail Assets taken as a whole, excluding the portion acquired by Collins & Wallace Holdings, LLC, to ACTOIL in exchange for cash equal to 25% of RSP LLC’s $121 million purchase price.
	RSP LLC allocated the net purchase price to the oil and natural gas properties acquired and asset retirement obligation assumed as follows (in thousands):
	Net purchase price	$	120,521
	25% NPI Sale to ACTOIL	(30,131		)
	Oil and natural gas properties acquired	$	90,390
	Asset retirement obligation assumed	296
	Oil and natural gas properties	$	90,686
	The Spanish Trail Acquisition was funded with a $70 million term loan, borrowings under the Company’s revolving credit facility (described below in Note 6) and the issuance of the NPI to ACTOIL described above.
	Resolute Sale
	Effective October 1, 2012, RSP LLC, ACTOIL and other minority non-operating working interest owners entered into a Purchase, Sale, and Option Agreement (“PSA”) to sell an undivided 32.35% interest in certain assets for an aggregate purchase price of $110 million to Resolute (the “Resolute Sale”). The Company’s share of the purchase price was $69 million and was recorded as a reduction to the basis of the underlying oil and natural gas properties. To the extent that the proceeds received exceeded the cost basis of the oil and natural gas properties, the Company recorded a gain on the sale. In addition, RSP LLC and the other sellers sold Resolute an option (the “Option”) for $5 million, $2.4 million of which was the Company’s share. The Option allowed Resolute to acquire the remaining 67.65% interest in these certain assets. The Option was non-refundable and only entitled Resolute to a limited time period during which it could exercise the right to acquire the remaining interest in these certain assets, and therefore the Option fee was included in the consideration transferred in computing the gain on disposition of the assets described above. The Company recorded a gain in connection with the sale of the 32.35% interest in these assets and the option fee in the amount of $6.7 million for the year ended December 31, 2012.
	In March 2013, Resolute exercised the right to acquire the 67.65% remaining interest in these assets from RSP LLC, ACTOIL and other working interest owners for an additional purchase price of approximately $230 million. RSP LLC’s share of the purchase price was $144.2 million. In connection with the transaction closing in March 2013, RSP LLC recorded a gain of approximately $6 million.
	The PSA contained customary closing conditions and included a $5 million title and environmental escrow (net to RSP LLC) and an $11 million indemnity escrow (net to RSP LLC) which were held back from the initial purchase price to provide for these contingencies. Amounts held in escrow for potential indemnity matters were not initially considered in the computation of the gain in connection with the sale of these certain assets because the Company could not reasonably estimate the potential outcome of any such matters at the time of the initial closing of the transaction.
	Subsequent to the initial closing, in October 2013, RSP LLC received the first two scheduled escrow payments under the terms of the PSA totaling approximately $12 million. The receipt of these funds substantially resolved any uncertainty associated with the ability to collect the remaining portion of the amounts held in escrow and, therefore, the Company recorded the gain associated with all funds received and the remaining escrow amounts not yet received as collectability of such amounts was deemed probable. For the twelve months ended December 31, 2013, the total gain recognized on the Resolute Sale was approximately $22.7 million.

Derivative_Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Instruments	'
	DERIVATIVE INSTRUMENTS
	Commodity Derivative Instruments
	The Company uses derivative instruments to manage its exposure to cash-flow variability from commodity-price risk inherent in its crude oil and natural gas production. These include over-the-counter (“OTC”) swaps and collars. The derivative instruments are recorded at fair value on the consolidated balance sheets and any gains and losses are recognized in current period earnings.
	Each swap transaction has an established fixed price. When the settlement price is above the fixed price, the Company pays its counterparty an amount equal to the difference between the settlement price and the fixed price multiplied by the hedged contract volume. When the settlement price is below the fixed price, the counterparty pays the Company an amount equal to the difference between the settlement price and the fixed price multiplied by the hedged contract volume.
	Each collar transaction has an established price floor and ceiling. When the settlement price is below the price floor established by these collars, the Company receives an amount from its counterparty equal to the difference between the settlement price and the price floor multiplied by the hedged contract volume. When the settlement price is above the price ceiling established by these collars, the Company pays its counterparty an amount equal to the difference between the settlement price and the price ceiling multiplied by the hedged contract volume.
	The following table summarizes all open positions as of June 30, 2014:
		Year			Year
		2014			2015
	Crude Oil Swaps:
	Notional volume (Bbl)	120,000			120,000
	Weighted average price ($/Bbl)(1)	$	94.5		$	92.6
	Crude Oil Collars:
	Notional volume (Bbl)	975,000			2,067,000
	Weighted average floor price ($/Bbl)(1)	$	87.09		$	86.7
	Weighted average ceiling price ($/Bbl)(1)	$	100.75		$	94.89
	Natural Gas Collars:
	Notional volume (Mmbtu)	750,000			—
	Weighted average floor price ($/Mmbtu)(2)	4			—
	Weighted average ceiling price ($/Mmbtu)(2)	4.78			—
	_______________________________________
	(1)         The crude oil derivative contracts are settled based on the month’s average daily NYMEX price of West Texas Intermediate Light Sweet Crude.
	(2)         The natural gas derivative contracts are settled based on the NYMEX Henry Hub closing settlement price.
	Fair Values and Gains (Losses)
	The following table presents the fair value of derivative instruments. The Company’s derivatives are presented as separate line items in its consolidated balance sheets as current and noncurrent derivative instrument assets and liabilities.  The fair value amounts are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under the terms of the Company’s master netting arrangements.
		Assets						Liabilities
		June 30, 2014			December 31, 2013			June 30, 2014			December 31, 2013
		(In thousands)
	Derivative Instruments:
	Current amounts
	Commodity contracts	$	1,629		$	671		$	(16,411	)	$	(1,562	)
	Noncurrent amounts
	Commodity contracts	2,101			1,078			(5,458		)	(43		)
	Total derivative instruments	$	3,730		$	1,749		$	(21,869	)	$	(1,605	)
	Gains and losses on derivatives are reported in the consolidated statements of operations.
	The following represents the Company’s reported gains and losses on derivative instruments for the periods presented:
		Three Months Ended June 30,
		2014			2013
		(In thousands)
	Loss on derivative instruments:
	Commodity derivative instruments	$	(15,958	)	$	934
	Interest rate derivative instruments	—			(12		)
	Total	$	(15,958	)	$	922
		Six Months Ended June 30,
		2014			2013
		(In thousands)
	Gain (loss) on derivative instruments:
	Commodity derivative instruments	$	(20,111	)	$	(719	)
	Interest rate derivative instruments	—			(16		)
	Total	$	(20,111	)	$	(735	)
	Offsetting of Derivative Assets and Liabilities
	The following table presents the Company’s gross and net derivative assets and liabilities.
		Gross Amount			Netting			Net
		Presented on			Adjustments(a)			Amount
		Balance Sheet
		(In thousands)
	30-Jun-14
	Derivative instrument assets with right of offset or master netting agreements	$	3,730		$	(3,730	)	$	—
	Derivative instrument liabilities with right of offset or master netting agreements	$	(21,869	)	$	3,730		$	(18,139	)
	December 31, 2013
	Derivative instrument assets with right of offset or master netting agreements	$	1,749		$	(1,332	)	$	417
	Derivative instrument liabilities with right of offset or master netting agreements	$	(1,605	)	$	1,332		$	(273	)
	_______________________________________
	(a)         With all of the Company’s financial trading counterparties, the Company has agreements in place that allow for the financial right of offset for derivative assets and derivative liabilities at settlement or in the event of a default under the agreements.
Credit-Risk Related Contingent Features in Derivatives
None of the Company’s derivative instruments contains credit-risk related contingent features. No amounts of collateral were posted by the Company related to net positions as of June 30, 2014 and December 31, 2013.

Fair_Value_Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	FAIR VALUE MEASUREMENTS
	The book values of cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities approximate fair value due to the short-term nature of these instruments.  The book value of the Company’s credit facilities approximate fair value as the interest rates are variable.  The fair value of derivative financial instruments is determined utilizing industry standard models using assumptions and inputs which are substantially observable in active markets throughout the full term of the instruments. These include market price curves, contract terms and prices, credit risk adjustments, implied market volatility and discount factors.
	The Company has categorized its assets and liabilities measured at fair value, based on the priority of inputs to the valuation technique, into a three-level fair value hierarchy. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3).
	Assets and liabilities recorded at fair value on the consolidated balance sheets are categorized based on the inputs to the valuation techniques as follows:
	•Level 1—Assets and liabilities recorded at fair value for which values are based on unadjusted quoted prices for identical assets or liabilities in an active market that management has the ability to access. Active markets are considered to be those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis.
	•Level 2—Assets and liabilities recorded at fair value for which values are based on quoted prices in markets that are not active or model inputs that are observable either directly or indirectly for substantially the full term of the asset or liability. Substantially all of these inputs are observable in the marketplace throughout the full term of the price risk management instrument and can be derived from observable data or supported by observable levels at which transactions are executed in the marketplace.
	•Level 3—Assets and liabilities recorded at fair value for which values are based on prices or valuation techniques that require inputs that are both unobservable and significant to the overall fair value measurement. Unobservable inputs that are not corroborated by market data. These inputs reflect management’s own assumptions about the assumptions a market participant would use in pricing the asset or liability.
	Valuation techniques that maximize the use of observable inputs are favored. Assets and liabilities are classified in their entirety based on the lowest priority level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the fair value hierarchy.
	Fair Value Measurement on a Recurring Basis
	The following table presents, by level within the fair value hierarchy, the Company’s assets and liabilities that are measured at fair value on a recurring basis.
		Level 1		Level 2			Level 3		Total fair value
		(In thousands)
	As of June 30, 2014:
	Commodity derivative instruments	$	—	$	(18,139	)	$	—	$	(18,139	)
	Total	$	—	$	(18,139	)	$	—	$	(18,139	)
		Level 1		Level 2			Level 3		Total fair value
		(In thousands)
	As of December 31, 2013:
	Commodity derivative instruments	$	—	$	144		$	—	$	144
	Total	$	—	$	144		$	—	$	144
	Significant Level 2 assumptions used to measure the fair value of the commodity derivative instruments include current market and contractual commodity prices, implied volatility factors, appropriate risk adjusted discount rates, as well as other relevant data.
	Reclassifications of fair value between Level 1, Level 2 and Level 3 of the fair value hierarchy, if applicable, are made at the end of each quarter. There were no transfers between Level 1, Level 2 or Level 3 during the three or six months ended June 30, 2014 and the year ended December 31, 2013.
	Nonfinancial Assets and Liabilities
	Assets and liabilities acquired in business combinations are recorded at their fair value on the date of acquisition. Significant Level 3 assumptions associated with the calculation of future cash flows used in the analysis of fair value of the oil and natural gas property acquired include the Company’s estimate of future commodity prices, production costs, development expenditures, production, risk-adjusted discount rates and other relevant data. Additionally, fair value is used to determine the inception value of the Company’s AROs. The inputs used to determine such fair value are primarily based upon costs incurred historically for similar work, as well as estimates from independent third parties for costs that would be incurred to restore leased property to the contractually stipulated condition. Additions to the Company’s AROs represent a nonrecurring Level 3 measurement.
	The Company reviews its proved oil and natural gas properties for impairment purposes by comparing the expected undiscounted future cash flows at a producing field level to the unamortized capitalized cost of the asset. Significant assumptions associated with the calculation of future cash flows used in the impairment analysis include the estimate of future commodity prices, production costs, development expenditures, production, risk-adjusted discount rates and other relevant data. As such, the fair value of oil and natural gas properties used in estimating impairment represents a nonrecurring Level 3 measurement.

Credit_Agreement

Credit Agreement	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Credit Agreement	'
	CREDIT AGREEMENT
	On September 10, 2013, in conjunction with the Spanish Trail Acquisition, the Company amended and restated its credit agreement, dated December 15, 2010, with Comerica Bank, as administrative agent providing for a revolving credit facility of up to $500 million, and expanded its syndicated bank group to 11 lenders.  In addition, the Company entered into a new term loan in the amount of $70 million to partially finance the Spanish Trail Acquisition. On June 9, 2014, the borrowing base under the revolving credit facility was increased from $300 million to $375 million as a result of the semiannual borrowing base redetermination under the Credit Agreement.
	The Company’s revolving credit facility requires it to maintain the following three financial ratios:
	•a working capital ratio, which is the ratio of consolidated current assets (includes unused commitments under its revolving credit facility and excludes restricted cash and derivative assets) to consolidated current liabilities (excluding the current portion of long-term debt under the credit facility and derivative liabilities), of not less than 1.0 to 1.0;
	•a minimum interest coverage ratio, which is the ratio of consolidated EBITDAX (as defined in the credit agreement) to consolidated interest expense, of not less than 3.0 to 1.0; and
	•a leverage ratio, which is the ratio of the sum of all of the Company’s debt to the consolidated EBITDAX (as defined in the credit agreement) for the four fiscal quarters then ended, of not greater than 4.0 to 1.0.
	The Company’s revolving credit facility contains restrictive covenants that may limit its ability to, among other things, incur additional indebtedness, make loans to others, make investments, enter into mergers, make or declare dividends, enter into commodity hedges exceeding a specified percentage or its expected production, enter into interest rate hedges exceeding a specified percentage of its outstanding indebtedness, incur liens, sell assets or engage in certain other transactions without the prior consent of the lenders.
	The Company was in compliance with such covenants and ratios as of June 30, 2014.
	Principal amounts borrowed are payable on the maturity date, and interest is payable quarterly for base rate loans and at the end of the applicable interest period for Eurodollar loans. RSP LLC has a choice of borrowing in Eurodollars or at the adjusted base rate. Eurodollar loans bear interest at a rate per annum equal to an adjusted LIBOR rate (equal to the quotient of: (i) the LIBOR Rate divided by (ii) a percentage equal to 100% minus the maximum rate on such date at which the Administrative Agent is required to maintain reserves on “Eurocurrency Liabilities” as defined in and pursuant to Regulation D of the Board of Governors of the Federal Reserve System) plus an applicable margin ranging from 125 to 200 basis points, depending on the percentage of its borrowing base utilized. Adjusted base rate loans bear interest at a rate per annum equal to the greatest of: (i) the agent bank’s reference rate; (ii) the federal funds effective rate plus 100 basis points; and (iii) the adjusted LIBOR rate plus 100 basis points, plus an applicable margin ranging from 25 to 100 basis points, depending on the percentage of its borrowing base utilized, plus a facility fee of 0.50% charged on the borrowing base amount. At June 30, 2014, the variable rate of interest under the Company’s revolving credit facility was 1.67%. The Company may repay any amounts borrowed prior to the maturity date without any premium or penalty other than customary LIBOR breakage costs. As of June 30, 2014, the revolving credit facility has a margin of 1.25% to 2.00% plus LIBOR, plus a facility fee of 0.50% charged on the borrowing base amount.
	The amount available to be borrowed under the revolving credit facility is subject to a borrowing base that is re-determined semiannually each May and November and depends on the volumes of proved oil and natural gas reserves and estimated cash flows from these reserves and commodity hedge positions. The borrowing base under the Company’s amended and restated credit agreement is $375 million as of June 30, 2014, with lender commitments of $500 million.
	The maturity date of the Company’s revolving credit facility is September 10, 2017.
	On January 23, 2014, the Company repaid the term loan in full, and as of June 30, 2014, the Company had no contractual obligations with respect to the term loan.

Commitments_and_Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	COMMITMENTS AND CONTINGENCIES
	Legal Matters
	In the ordinary course of business, the Company may at times be subject to claims and legal actions. Management believes it is remote that the impact of such matters will have a material adverse effect on the Company’s financial position, results of operations or cash flows.
	Environmental Matters
	The Company is subject to various federal, state and local laws and regulations relating to the protection of the environment. These laws, which are often changing, regulate the discharge of materials into the environment and may require the Company to remove or mitigate the environmental effects of the disposal or release of petroleum or chemical substances at various sites. Environmental expenditures are expensed as incurred. The Company has established procedures for the ongoing evaluation of its operations to identify potential environmental exposures and to comply with regulatory policies and procedures.
	The Company accounts for environmental contingencies in accordance with the accounting guidance related to accounting for contingencies. Environmental expenditures that relate to current operations are expensed or capitalized as appropriate. Expenditures that relate to an existing condition caused by past operations, which do not contribute to current or future revenue generation, are expensed.
	Liabilities are recorded when environmental assessments and/or clean-ups are probable and the costs can be reasonably estimated. Such liabilities are generally undiscounted unless the timing of cash payments is fixed and readily determinable. At June 30, 2014 and December 31, 2013, the Company had no environmental matters requiring specific disclosure or requiring the recognition of a liability.
	Leases
	During 2011, RSP LLC entered into a month-to-month operating lease agreement and a long-term operating lease agreement for office space.  During February 2014, the Company entered into a 64-month lease agreement through May 2019 for office space.  Rent expense for the three months ended June 30, 2014 and 2013 was $78 thousand and $63 thousand, respectively. Rent expense for the six months ended June 30, 2014 and 2013 was $161 thousand and $125 thousand, respectively.

EquityBased_Compensation

Equity-Based Compensation	6 Months Ended
	Jun. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Equity-Based Compensation	'
	EQUITY-BASED COMPENSATION
	Share-based compensation expense, which was recorded in "General and administrative expenses" in the accompanying consolidated statements of operations, was $1.7 million and $13.7 million for the three and six months ended June 30, 2014. Share-based compensation expense includes certain costs which are non-recurring; expense for restricted shares which were issued as a bonus related to our IPO along with incentive unit expense that will ultimately be borne by RSP Permian Holdco, L.L.C.
	Restricted Stock Awards
	In connection with the IPO, the Company adopted the RSP Permian, Inc. 2014 Long Term Incentive Plan (the “LTIP”) for the employees, consultants and directors of the Company and its affiliates who perform services for the Company.  Refer to “Part III, Item 11. Executive Compensation” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013 for additional information related to these equity-based compensation plans.
	Share-based compensation expense for these awards was $1.3 million for the three months and $2.1 million for the six months ended June 30, 2014.  The Company views restricted stock awards with graded vesting as single awards with an expected life equal to the average expected life and amortize the awards on a straight-line basis over the life of the awards.
	The compensation expense for these awards was determined based on the market price of the Company’s common stock at the date of grant applied to the total number of shares that were anticipated to fully vest. As of June 30, 2014, the Company had unrecognized compensation expense of $9.0 million related to restricted stock awards which is expected to be recognized over a weighted average period of 2.0 years.
	The following table represents restricted stock award activity for the six months ended June 30, 2014:
		Shares	Wtd. Avg. Grant Price
	Restricted shares outstanding, beginning of period	—	$	—
	Restricted shares granted	463,951	23.51
	Restricted shares outstanding, end of period	463,951	$	23.51
	Performance-Based Restricted Stock Awards
	In June 2014, performance-based restricted stock awards were granted containing predetermined market conditions with a cliff vesting period of 2.75 years. We granted 134,400 of these shares at a 100% of target payout while the conditions of the grants allow for a payout ranging between no payout and 200% of target.
	Share-based compensation for these awards was $0.1 million for both the three months and six months ended June 30, 2014. The compensation expense for the market condition is based on a grant date valuation of $28.14 per share using a Monte-Carlo simulation. The unrecognized compensation expense related to these shares is approximately $3.8 million as of June 30, 2014 and is expected to be recognized over the next 2.70 years. The payout level is calculated based on actual performance achieved during the performance period compared to a defined peer group.
	Incentive Units
	Pursuant to the LLC Agreement of RSP LLC, certain incentive units are available to be issued to the Company’s management and employees, consisting of Tier I, Tier I A, Tier II, Tier III and Tier IV units. The incentive units are intended to be compensation for services rendered to the Company. All incentive units, whether vested or not, are forfeited if payouts are not achieved by a specified date. Tier I and Tier I A incentive units vest ratably over three years but are subject to forfeiture if payout is not achieved. Tier I and Tier I A payout is realized upon the return of members’ invested capital and a specified rate of return. Tiers II, III and IV incentive units vest only upon the achievement of certain distribution thresholds for each such Tier and each Tier of the incentive units is subject to forfeiture if the applicable required payouts are not achieved.  In addition, vested and unvested units will be forfeited if an incentive unit holder’s employment is terminated for cause or if the unitholder voluntarily terminates his or her employment.
	In connection with the IPO, the incentive units of RSP LLC became incentive units in RSP Permian Holdco, L.L.C. and therefore based upon distributions to members of RSP Permian Holdco, L.L.C. rather than members of RSP LLC.  The terms and conditions of the profits interest awards remained substantially similar to the terms applicable to the incentive unit awards prior to the IPO, including the retention of existing vesting schedules.  See “Part III, Item 11. Executive Compensation” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013 for additional information regarding the incentive units.
	The achievement of payout conditions is a performance condition that requires the Company to assess, at each reporting period, the probability that an event of payout will occur. Compensation cost is required to be recognized at such time that the payout terms are probable of being met. At the grant dates and subsequent reporting periods, the Company did not deem as probable that such payouts would be achieved for any Tier of incentive units.
	At such time that the occurrence of the performance conditions associated with these incentive units are deemed probable, the Company will record a non-cash compensation expense based upon the grant date fair value of the incentive units that are probable of reaching payout as a result of reaching established distribution thresholds. As of December 31, 2013, the unrecognized non-cash compensation expense associated with all tiers of the incentive units was approximately $16.3 million. After successful completion of the IPO, the performance conditions associated with the Tier I, Tier I A and Tier II incentive units were deemed probable of reaching payout, which resulted in the recognition of non-cash compensation expense of $0.2 million and $11.4 million for the three and six months ended June 30, 2014. The Tier I A and Tier II incentive units will have a remaining unrecognized non-cash compensation expense of approximately $1.3 million which will be amortized over the remaining service period and result in a $0.5 million non-cash compensation expense in the remainder of 2014 and $0.8 million in 2015. The remaining unrecognized non-cash compensation expense related to the Tier III and Tier IV incentive units is approximately $3.5 million and will be recognized when it is deemed that the Tier III and Tier IV incentive units are probable of reaching payout as a result of reaching the established distribution thresholds.

Earnings_Per_Share_Pro_Forma_E

Earnings Per Share & Pro Forma Earnings Per Share	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Earnings Per Share & Pro Forma Earnings Per Share	'
	EARNINGS PER SHARE & PRO FORMA EARNINGS PER SHARE
	Earnings per Share
	The Company’s basic earnings per share amounts have been computed using the two-class method based on the weighted-average number of shares of common stock outstanding for the period.  Because the Company recognized a net loss for the six months ended June 30, 2014, unvested restricted share awards were not recognized in dilutive earnings per share calculations as they would be antidilutive.  A reconciliation of the components of basic and diluted earnings per common share is presented in the table below:
			Three Months Ended		Six Months Ended June 30, 2014
			June 30, 2014
			(In thousands)
	Numerator:
	Net income (loss) available to stockholders		$	8,226	$	(119,303	)
	Basic net income (loss) allocable to participating securities (1)		49		—
	Income (loss) available to stockholders		$	8,177	$	(119,303	)
	Denominator:
	Weighted average number of common shares outstanding - basic		72,500		67,702
	Effect of dilutive securities:
	Restricted stock		—		—
	Weighted average number of common shares outstanding - diluted (2)		72,500		67,702
	Net loss per share:
	Basic		$	0.11	$	(1.76	)
	Diluted		$	0.11	$	(1.76	)
	_______________________________________
	(1)    Restricted share awards that contain non-forfeitable rights to dividends are participating securities and, therefore, are included in computing earnings using the two-class method. Participating securities, however, do not participate in undistributed net losses.
	(2) Approximately 0.1 million shares related to performance-based restricted stock units that could be converted to common shares in the future based on predetermined performance and market goals were not included in the computation of Diluted earnings per share for the three months ended June 30, 2014, because the performance and market conditions had not been met, assuming the end of the reporting period was the end of the contingency period.
	Pro Forma Earnings per Share
	The Company computed a pro forma income tax provision as if the Company was subject to income taxes since January 1, 2014. The pro forma tax provision has been calculated at a rate based upon a federal corporate level tax rate and a state tax rate, net of federal benefit, and excludes the non-recurring tax adjustment related to the conversion of the Company from an LLC to a corporation on January 23, 2014, as further described in Note 2 under “Income Taxes.”
	The Company’s pro forma basic earnings per share amounts have been computed based on the weighted-average number of shares of common stock outstanding for the period, as if the common shares issued in the IPO were outstanding for the entire year. A reconciliation of the components of pro forma basic and diluted earnings per common share is presented in the table below:
		Six Months Ended
		June 30, 2014
	Numerator:
	Income before taxes, as reported	$	20,859
	Pro forma provision for income taxes	7,509
	Pro forma net income available to stockholders	13,350
	Basic net income allocable to participating securities	82
	Pro forma net income available to stockholders	$	13,268
	Denominator:
	Weighted average number of common shares outstanding - basic	72,500
	Effect of dilutive securities:
	Restricted stock	—
	Weighted average number of common shares outstanding - diluted	72,500
	Net income per share:
	Basic	$	0.18
	Diluted	$	0.18
	For the three months ended June 30, 2014, our actual earnings per share are equal to our pro forma earnings per share.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Basis of Presentation	'
	Basis of Presentation
	These financial statements have been prepared by the Company pursuant to the rules and regulations of the SEC. They reflect all adjustments that are, in the opinion of management, necessary for a fair statement of the results for interim periods, on a basis consistent with the audited annual financial statements. All such adjustments are of a normal recurring nature. Certain information, accounting policies and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) have been omitted pursuant to such rules and regulations, although the Company believes the disclosures are adequate to make the information presented not misleading. These financial statements should be read together with the financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013.
Use of Estimates	'
	Use of Estimates
	The preparation of the consolidated financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities in the financial statements and accompanying notes. Although management believes these estimates are reasonable, actual results could differ from these estimates. Changes in estimates are recorded prospectively. Significant assumptions are required in the valuation of proved oil and natural gas reserves that may affect the amount at which oil and natural gas properties are recorded. Estimation of asset retirement obligations (“AROs”) and valuations of derivative instruments and the fair value of incentive unit compensation also require significant assumptions. It is possible that these estimates could be revised at future dates and these revisions could be material. Depletion of oil and natural gas properties are determined using estimates of proved oil and natural gas reserves. There are numerous uncertainties inherent in the estimation of quantities of proved reserves and in the projection of future rates of production and the timing of development expenditures. Similarly, evaluations for impairment of proved and unproved oil and natural gas properties are subject to numerous uncertainties including, among others, estimates of future recoverable reserves and commodity price estimates.
Reclassifications	'
	Reclassifications
	Certain reclassifications have been made to prior periods to conform to current period presentation.
Oil and Natural Gas Properties	'
	In some circumstances, it may be uncertain whether proved commercial reserves have been found when drilling has been completed. Such exploratory well drilling costs may continue to be capitalized if the anticipated reserve quantity is sufficient to justify its completion as a producing well and sufficient progress in assessing the reserves and the economic and operating viability of the project is being made. As of June 30, 2014 and December 31, 2013, there were no costs capitalized in connection with exploratory wells in progress.
	Capitalized costs are evaluated for impairment whenever events or changes in circumstances indicate that an asset’s carrying amount may not be recoverable. To determine if a depletable unit (field) is impaired, the Company compares the carrying value of the depletable unit to the undiscounted future net cash flows by applying estimates of future oil and natural gas prices to the estimated future production of oil and natural gas reserves over the economic life of the property and deducting future costs. Future net cash flows are based upon reservoir engineers’ estimates of proved reserves.
	For a property determined to be impaired, an impairment loss equal to the difference between the property’s carrying value and estimated fair value is recognized. Fair value, on a field basis, is estimated to be the present value of the aforementioned expected future net cash flows. Unproved properties are assessed periodically to determine whether they have been impaired. An impairment allowance is provided on an unproved property when the Company determines that the property will not be developed. Each part of this calculation is subject to a large degree of judgment, including the determination of the depletable units’ estimated reserves, future net cash flows and fair value.  No impairment of proved property was recorded for the three or six months ended June 30, 2014 or 2013.
	Natural gas volumes are converted to Boe at the rate of six Mcf of natural gas to one Bbl of oil. This convention is not an equivalent price basis and there may be a large difference in value between an equivalent volume of oil versus an equivalent volume of natural gas. NGL volumes are stated in barrels.
	Oil and Natural Gas Properties
	The Company uses the successful efforts method of accounting for its oil and natural gas exploration and production activities. Costs incurred by the Company related to the acquisition of oil and natural gas properties and the cost of drilling development wells and successful exploratory wells are capitalized, while the costs of unsuccessful exploratory wells are expensed when determined to be unsuccessful.
	The Company capitalizes interest on expenditures while activities are in progress to bring the assets to their intended use for significant exploration and development projects that last more than six months. The Company did not capitalize any interest in the six months ended June 30, 2014 and 2013 as no projects lasted more than six months. Costs incurred to maintain wells and related equipment, lease and well operating costs and other exploration costs are expensed as incurred. Gains and losses arising from the sale of properties are generally included in operating income. Unproved properties are assessed periodically for possible impairment.
	Capitalized acquisition costs attributable to proved oil and natural gas properties and leasehold costs are depleted on a field basis based on proved reserves using the unit-of-production method. Capitalized exploration well costs and development costs, including AROs, are depleted on a field basis, based on proved developed reserves. For the three months ended June 30, 2014 and 2013, depletion expense for oil and natural gas producing property was $21.6 million and $11.5 million, respectively. For the six months ended June 30, 2014 and 2013, depletion expense for oil and natural gas producing property was $37.9 million and $21.7 million, respectively. Depletion expense is included in depreciation, depletion and amortization in the accompanying consolidated statements of operations.
Asset Retirement Obligation	'
	Asset Retirement Obligation
	The Company records AROs related to the retirement of long-lived assets at the time a legal obligation is incurred and the liability can be reasonably estimated. AROs are recorded as long-term liabilities with a corresponding increase in the carrying amount of the related long-lived asset. Subsequently, the asset retirement cost included in the carrying amount of the related asset is allocated to expense through depletion of the asset. Changes in the liability due to passage of time are generally recognized as an increase in the carrying amount of the liability and as corresponding accretion expense.
	The Company estimates a fair value of the obligation on each well in which it owns an interest by identifying costs associated with the future down-hole plugging, dismantlement and removal of production equipment and facilities, and the restoration and reclamation of a field’s surface to a condition similar to that existing before oil and natural gas extraction began.
	In general, the amount of ARO and the costs capitalized will be equal to the estimated future cost to satisfy the abandonment obligation using current prices that are escalated by an assumed inflation factor up to the estimated settlement date which is then discounted back to the date that the abandonment obligation was incurred using an estimated credit adjusted rate. If the estimated ARO changes, an adjustment is recorded to both the ARO and the long-lived asset. Revisions to estimated AROs can result from changes in retirement cost estimates, revisions to estimated inflation rates and changes in the estimated timing of abandonment.
	After recording these amounts, the ARO is accreted to its future estimated value using the same assumed credit adjusted rate and the associated capitalized costs are depreciated on a unit-of-production basis.
Income Taxes	'
	Income Taxes
	RSP LLC was organized as a limited liability company and treated as a flow-through entity for federal income tax purposes.  As such, taxable income and any related tax credits were passed through to its members and are included in their tax returns even though such net taxable income or tax credits may not have actually been distributed. Accordingly, provision for federal and state corporate income taxes has been made only for the operations of RSP Inc. from January 23, 2014 through June 30, 2014 in the accompanying consolidated financial statements. Deferred income taxes are provided to reflect the future tax consequences or benefits of differences between the tax basis of assets and liabilities and their reported amounts in the financial statements using enacted tax rates. Upon the conversion from a limited liability company to a corporation on January 23, 2014, the Company established a $132 million provision for deferred income taxes, which was recognized as tax expense from continuing operations.  The primary upward adjustments in the effective tax rate above the U.S. statutory rate are the adjustment related to converting from a limited liability company to a corporation noted above along with non-deductible incentive unit compensation.
	Deferred taxes are determined based on the estimated future tax effects of differences between the financial statement and tax basis of assets and liabilities, given the provisions of enacted tax laws. Tax positions are evaluated for recognition using a more-likely-than-not threshold, and those tax positions requiring recognition are measured as the largest amount of tax benefit that is greater than fifty percent likely of being realized upon ultimate settlement with a taxing authority that has full knowledge of all relevant information. The Company’s policy is to record interest and penalties relating to uncertain tax positions in income tax expense. At June 30, 2014, the Company did not have any accrued liability for uncertain tax positions and does not anticipate recognition of any significant liabilities for uncertain tax positions during the next 12 months.
	The Company’s U.S. federal income tax returns and Texas franchise tax returns for 2010 and beyond remain subject to examination by the taxing authorities. There are no material unresolved items related to periods previously audited by these taxing authorities. No other jurisdiction’s returns are significant to the Company’s financial position.
New Accounting Pronouncements	'
	New Accounting Pronouncements
	In May 2014, the Financial Accounting Standards Board ("FASB") issued ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” which provides a comprehensive revenue recognition standard for contracts with customers that supersedes current revenue recognition guidance including industry specific guidance. An entity is required to apply ASU 2014-09 for annual and interim reporting periods beginning after December 15, 2016. An entity can apply ASU 2014-09 using either a full retrospective method, meaning the standard is applied to all of the periods presented, or a modified retrospective method, meaning the cumulative effect of initially applying the standard is recognized in the most current period presented in the financial statements. The Company is evaluating the impact that this new guidance will have on its consolidated financial statements.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Schedule of Accounts Receivable from Related Parties	'
	The Company’s accounts receivable from related parties as of June 30, 2014 was $1.1 million and was owed by Collins, Wallace LP, Collins & Wallace Holdings, LLC, and Pecos. The balance as of December 31, 2013 was $3.7 million and was owed by Wallace LP.
Schedule of Oil and Natural Gas Properties	'
	The Company’s oil and natural gas properties as of June 30, 2014 and December 31, 2013 consisted of the following:
			June 30, 2014			December 31, 2013
			(In thousands)
	Proved oil and natural gas properties		$	1,157,129		$	562,019
	Unproved oil and natural gas properties		508,878			33,467
	Total oil and natural gas properties		1,666,007			595,486
	Less: accumulated depletion		(117,415		)	(88,514		)
	Total oil and natural gas properties, net		$	1,548,592		$	506,972
Schedule of Changes in Asset Retirement Obligation	'
	The ARO consisted of the following for the period indicated:
		Six Months Ended
		June 30, 2014
		(In thousands)
	Asset retirement obligation at beginning of period	$	2,584
	Liabilities assumed	2,342
	Accretion expense	66
	Asset retirement obligation at end of period	$	4,992
Schedule of Income Tax Expense	'
	The following is an analysis of the Company’s consolidated income tax expense:
			Three Months Ended June 30,						Six Months Ended June 30,
			2014			2013			2014		2013
			(In thousands)						(In thousands)
	Current		$	805		$	68		$	1,676	$	68
	Deferred		4,143			—			138,486		—
	Income Tax Expense		$	4,948		$	68		$	140,162	$	68

Acquisitions_and_Sales_of_Oil_1

Acquisitions and Sales of Oil and Natural Gas Property Interests (Tables)	6 Months Ended
	Jun. 30, 2014
Business Acquisition [Line Items]	'
Unaudited Pro Forma Financial Information	'
	The unaudited pro forma financial information does not purport to be indicative of results of operations that would have occurred had the transaction occurred on the basis assumed above, nor is such information indicative of expected future results of operations.
			Three Months Ended June 30, 2014						Three Months Ended June 30, 2013
			Actual			Pro Forma			Actual		Pro Forma
			(In thousands)						(In thousands)
	Revenues		$	74,062		$	74,062		$	25,148	$	47,377
	Net income (loss)		$	8,226		$	8,226		$	7,859	$	17,190
			Six Months Ended June 30, 2014						Six Months Ended June 30, 2013
			Actual			Pro Forma			Actual		Pro Forma
			(In thousands)						(In thousands)
	Revenues		$	131,821		$	136,806		$	49,803	$	80,568
	Net income (loss)		$	(119,303	)	$	(119,059	)	$	20,725	$	25,136
ACTOIL NPI Repurchase [Member]	'
Business Acquisition [Line Items]	'
Schedule of Significant Asset Acquisition	'
	A summary of the consideration transferred and the assets acquired and liabilities acquired in connection with the ACTOIL NPI Repurchase is as follows (in thousands):
	Value of the 10,816,626 shares of the Company’s common stock issued in the ACTOIL NPI Repurchase	$	210,924
	Elimination of NPI payable	(36,931		)
	Total consideration for the assets contributed in the ACTOIL NPI Repurchase	$	173,993
	Oil and natural gas properties cost	$	158,115
	Asset retirement obligation	(639		)
	Deferred tax asset*	16,517
	Total net assets acquired	$	173,993
	_______________________________________
	*       Amount represents the estimated book to tax difference in oil and natural gas properties as of the acquisition date on a tax-effected basis of approximately 35%.
Collins and Wallace Contributions [Member]	'
Business Acquisition [Line Items]	'
Schedule of Consideration Transferred, Assets Acquired and Liabilities Assumed	'
	A summary of the consideration transferred and the fair value of assets and liabilities acquired in connection with the Collins and Wallace Contributions is as follows (in thousands):
	Value of the 22,023,654 shares of the Company’s common stock issued in the Collins and Wallace Contributions	$	429,461
	Cash paid in the Collins and Wallace Contributions	2,219
	Total consideration for the assets contributed in the Collins and Wallace Contributions	$	431,680
	Fair value of oil and natural gas properties	$	644,052
	Asset retirement obligation	(1,063		)
	Deferred tax liability*	(211,309		)
	Total net assets acquired	$	431,680
	_______________________________________
	*       Amount represents the estimated book to tax difference in oil and natural gas properties as of the acquisition date on a tax-effected basis of approximately 35%.
Spanish Trail Acquisition [Member]	'
Business Acquisition [Line Items]	'
Schedule of Consideration Transferred, Assets Acquired and Liabilities Assumed	'
	RSP LLC allocated the net purchase price to the oil and natural gas properties acquired and asset retirement obligation assumed as follows (in thousands):
	Net purchase price	$	120,521
	25% NPI Sale to ACTOIL	(30,131		)
	Oil and natural gas properties acquired	$	90,390
	Asset retirement obligation assumed	296
	Oil and natural gas properties	$	90,686

Derivative_Instruments_Tables

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of Notional Amounts of Outstanding Derivative Positions	'
	The following table summarizes all open positions as of June 30, 2014:
		Year			Year
		2014			2015
	Crude Oil Swaps:
	Notional volume (Bbl)	120,000			120,000
	Weighted average price ($/Bbl)(1)	$	94.5		$	92.6
	Crude Oil Collars:
	Notional volume (Bbl)	975,000			2,067,000
	Weighted average floor price ($/Bbl)(1)	$	87.09		$	86.7
	Weighted average ceiling price ($/Bbl)(1)	$	100.75		$	94.89
	Natural Gas Collars:
	Notional volume (Mmbtu)	750,000			—
	Weighted average floor price ($/Mmbtu)(2)	4			—
	Weighted average ceiling price ($/Mmbtu)(2)	4.78			—
	_______________________________________
	(1)         The crude oil derivative contracts are settled based on the month’s average daily NYMEX price of West Texas Intermediate Light Sweet Crude.
	(2)         The natural gas derivative contracts are settled based on the NYMEX Henry Hub closing settlement price.
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value, Gross Basis	'
	The fair value amounts are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under the terms of the Company’s master netting arrangements.
		Assets						Liabilities
		June 30, 2014			December 31, 2013			June 30, 2014			December 31, 2013
		(In thousands)
	Derivative Instruments:
	Current amounts
	Commodity contracts	$	1,629		$	671		$	(16,411	)	$	(1,562	)
	Noncurrent amounts
	Commodity contracts	2,101			1,078			(5,458		)	(43		)
	Total derivative instruments	$	3,730		$	1,749		$	(21,869	)	$	(1,605	)
Derivative Instruments, Gains (Losses)	'
	The following represents the Company’s reported gains and losses on derivative instruments for the periods presented:
		Three Months Ended June 30,
		2014			2013
		(In thousands)
	Loss on derivative instruments:
	Commodity derivative instruments	$	(15,958	)	$	934
	Interest rate derivative instruments	—			(12		)
	Total	$	(15,958	)	$	922
		Six Months Ended June 30,
		2014			2013
		(In thousands)
	Gain (loss) on derivative instruments:
	Commodity derivative instruments	$	(20,111	)	$	(719	)
	Interest rate derivative instruments	—			(16		)
	Total	$	(20,111	)	$	(735	)
Gross and Net Derivative Assets	'
	The following table presents the Company’s gross and net derivative assets and liabilities.
		Gross Amount			Netting			Net
		Presented on			Adjustments(a)			Amount
		Balance Sheet
		(In thousands)
	30-Jun-14
	Derivative instrument assets with right of offset or master netting agreements	$	3,730		$	(3,730	)	$	—
	Derivative instrument liabilities with right of offset or master netting agreements	$	(21,869	)	$	3,730		$	(18,139	)
	December 31, 2013
	Derivative instrument assets with right of offset or master netting agreements	$	1,749		$	(1,332	)	$	417
	Derivative instrument liabilities with right of offset or master netting agreements	$	(1,605	)	$	1,332		$	(273	)
	_______________________________________
	(a)         With all of the Company’s financial trading counterparties, the Company has agreements in place that allow for the financial right of offset for derivative assets and derivative liabilities at settlement or in the event of a default under the agreements.
Gross and Net Derivative Liabilities	'
	The following table presents the Company’s gross and net derivative assets and liabilities.
		Gross Amount			Netting			Net
		Presented on			Adjustments(a)			Amount
		Balance Sheet
		(In thousands)
	30-Jun-14
	Derivative instrument assets with right of offset or master netting agreements	$	3,730		$	(3,730	)	$	—
	Derivative instrument liabilities with right of offset or master netting agreements	$	(21,869	)	$	3,730		$	(18,139	)
	December 31, 2013
	Derivative instrument assets with right of offset or master netting agreements	$	1,749		$	(1,332	)	$	417
	Derivative instrument liabilities with right of offset or master netting agreements	$	(1,605	)	$	1,332		$	(273	)
	_______________________________________
	(a)         With all of the Company’s financial trading counterparties, the Company has agreements in place that allow for the financial right of offset for derivative assets and derivative liabilities at settlement or in the event of a default under the agreements.

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 presents, by level within the fair value hierarchy, the Company’s assets and liabilities that are measured at fair value on a recurring basis.
		Level 1		Level 2			Level 3		Total fair value
		(In thousands)
	As of June 30, 2014:
	Commodity derivative instruments	$	—	$	(18,139	)	$	—	$	(18,139	)
	Total	$	—	$	(18,139	)	$	—	$	(18,139	)
		Level 1		Level 2			Level 3		Total fair value
		(In thousands)
	As of December 31, 2013:
	Commodity derivative instruments	$	—	$	144		$	—	$	144
	Total	$	—	$	144		$	—	$	144

EquityBased_Compensation_Table

Equity-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Schedule of Share-based Compensation, Restricted Stock Award Activity	'
	The following table represents restricted stock award activity for the six months ended June 30, 2014:
		Shares	Wtd. Avg. Grant Price
	Restricted shares outstanding, beginning of period	—	$	—
	Restricted shares granted	463,951	23.51
	Restricted shares outstanding, end of period	463,951	$	23.51

Earnings_Per_Share_Pro_Forma_E1

Earnings Per Share & Pro Forma Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Schedule of Earnings Per Share, Basic and Diluted	'
	A reconciliation of the components of basic and diluted earnings per common share is presented in the table below:
			Three Months Ended		Six Months Ended June 30, 2014
			June 30, 2014
			(In thousands)
	Numerator:
	Net income (loss) available to stockholders		$	8,226	$	(119,303	)
	Basic net income (loss) allocable to participating securities (1)		49		—
	Income (loss) available to stockholders		$	8,177	$	(119,303	)
	Denominator:
	Weighted average number of common shares outstanding - basic		72,500		67,702
	Effect of dilutive securities:
	Restricted stock		—		—
	Weighted average number of common shares outstanding - diluted (2)		72,500		67,702
	Net loss per share:
	Basic		$	0.11	$	(1.76	)
	Diluted		$	0.11	$	(1.76	)
	_______________________________________
	(1)    Restricted share awards that contain non-forfeitable rights to dividends are participating securities and, therefore, are included in computing earnings using the two-class method. Participating securities, however, do not participate in undistributed net losses.
Schedule of Pro Forma Earnings Per Share, Basic and Diluted	'
	A reconciliation of the components of pro forma basic and diluted earnings per common share is presented in the table below:
		Six Months Ended
		June 30, 2014
	Numerator:
	Income before taxes, as reported	$	20,859
	Pro forma provision for income taxes	7,509
	Pro forma net income available to stockholders	13,350
	Basic net income allocable to participating securities	82
	Pro forma net income available to stockholders	$	13,268
	Denominator:
	Weighted average number of common shares outstanding - basic	72,500
	Effect of dilutive securities:
	Restricted stock	—
	Weighted average number of common shares outstanding - diluted	72,500
	Net income per share:
	Basic	$	0.18
	Diluted	$	0.18
	For the three months ended June 30, 2014, our actual earnings per share are equal to our pro forma earnings per share.

Nature_of_Operations_and_Basis1

Nature of Operations and Basis of Presentation (Details) (USD $)	6 Months Ended		0 Months Ended	1 Months Ended	0 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Aug. 12, 2014	Jul. 31, 2014	Jan. 23, 2014	Jan. 23, 2014	Jan. 23, 2014	Jan. 23, 2014	Jan. 23, 2014	Jan. 23, 2014
			Subsequent event [Member]	Glasscock County [Member]	IPO and secondary offering [Member]	IPO [Member]	IPO [Member]	IPO [Member]	IPO [Member]	Secondary offering [Member]
				Subsequent event [Member]			ACTOIL, LLC [Member]	Revolving credit facility [Member]	Term loan [Member]
Subsidiary, Sale of Stock [Line Items]	'	'	'	'	'	'	'	'	'	'
Total number of shares sold in the IPO	'	'	11,500,000	'	23,000,000	'	'	'	'	'
Sale of common stock in IPO (in dollars per share)	'	'	$25.65	'	$19.50	'	'	'	'	'
Total proceeds raised in the IPO	'	'	'	'	$449,000,000	'	'	'	'	'
Shares of common stock sold in the IPO by RSP, Inc	'	'	4,800,000	'	'	9,200,000	'	'	'	'
Issuance of common stock	163,082,000	0	'	'	'	163,000,000	'	'	'	'
Repayment of term loan	'	'	'	'	'	'	'	'	70,000,000	'
Repayment of revolving credit facility	'	'	'	'	'	'	'	56,000,000	'	'
Number of shares sold in IPO by existing stockholders	'	'	6,700,000	'	'	'	'	'	'	13,800,000
Net profits interest (percent)	'	'	'	'	'	'	25.00%	'	'	'
Purchase price to acquire oil and gas properties	268,886,000	88,187,000	'	259,000,000	'	'	'	'	'	'
Proceeds from sale of common stock	'	'	$117,800,000	'	'	'	'	'	'	'

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Accounts Receivable, Related Parties) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts receivable, related party	$1,107	$3,672
Collins [Member]	'	'
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts receivable, related party	'	$3,700

Summary_of_Significant_Account4

Summary of Significant Accounting Policies (Oil and Natural Gas) (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
			Boe
Accounting Policies [Abstract]	'	'	'	'	'
Minimum project term to capitalize interest	'	'	'6 months	'6 months	'
Depletion expense	$21,600,000	$11,500,000	$37,900,000	$21,700,000	'
Costs capitalized in connection with exploratory wells in progress	0	'	0	'	0
Impairment of proved properties	'	'	0	0	'
Conversion of natural gas volumes to barrel of oil equivalent	'	'	6	'	'
Oil and Natural Gas Properties [Abstract]	'	'	'	'	'
Proved oil and natural gas properties	1,157,129,000	'	1,157,129,000	'	562,019,000
Unproved oil and natural gas properties	508,878,000	'	508,878,000	'	33,467,000
Total oil and natural gas properties	1,666,007,000	'	1,666,007,000	'	595,486,000
Less: accumulated depletion	-117,415,000	'	-117,415,000	'	-88,514,000
Total oil and natural gas properties, net	$1,548,592,000	'	$1,548,592,000	'	$506,972,000

Summary_of_Significant_Account5

Summary of Significant Accounting Policies (Asset Retirement Obligation) (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'	'	'
Asset retirement obligation at beginning of period	'	'	$2,584	'
Liabilities assumed	'	'	2,342	'
Accretion expense	38	26	66	51
Asset retirement obligation at end of period	$4,992	'	$4,992	'

Summary_of_Significant_Account6

Summary of Significant Accounting Policies (Income Taxes) (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jan. 23, 2014
Accounting Policies [Abstract]	'	'	'	'	'
Provision for deferred income taxes	'	'	'	'	$132,000,000
Income Tax Expense (Benefit) [Abstract]	'	'	'	'	'
Current	805,000	68,000	1,676,000	68,000	'
Deferred	4,143,000	0	138,486,000	0	'
Income Tax Expense	$4,948,000	$68,000	$140,162,000	$68,000	'

Acquisitions_and_Sales_of_Oil_2

Acquisitions and Sales of Oil and Natural Gas Property Interests (Pro Forma Results) (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Business Acquisition, Pro Forma Information [Line Items]	'	'	'	'
Revenues	$74,062	$25,148	$131,821	$49,803
Net income (loss)	8,226	7,859	-119,303	20,725
Pro Forma [Member]	'	'	'	'
Business Acquisition, Pro Forma Information [Line Items]	'	'	'	'
Revenues	74,062	47,377	136,806	80,568
Net income (loss)	$8,226	$17,190	($119,059)	$25,136

Acquisitions_and_Sales_of_Oil_3

Acquisitions and Sales of Oil and Natural Gas Property Interests (Collins and Wallace) (Details) (USD $)	6 Months Ended		0 Months Ended			6 Months Ended	1 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jan. 23, 2014	Jan. 23, 2014	Jan. 23, 2014	Jun. 30, 2014	Jul. 31, 2014
			Collins and Wallace Contributions [Member]	Collins and Wallace Contributions [Member]	Collins and Wallace Contributions [Member]	Martin, Glasscock and Dawson counties [Member]	Glasscock County [Member]
				Collins [Member]	Wallace LP [Member]	transaction	Subsequent event [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'	'
Purchase price to acquire oil and gas properties	$268,886,000	$88,187,000	'	'	'	$79,000,000	$259,000,000
Number of oil and gas property acquisitions	'	'	'	'	'	3	'
Capitalized costs, proved oil and natural gas properties	'	'	'	'	'	69,000,000	'
Consideration Transferred [Abstract]	'	'	'	'	'	'	'
Number of common shares issued in acquisition	'	'	22,023,654	'	'	'	'
Common stock issued for oil and gas properties	677,402,000	0	429,461,000	'	'	'	'
Cash paid in the Collins and Wallace Contributions	'	'	2,219,000	1,600,000	600,000	'	'
Total consideration for the assets contributed in the Collins and Wallace Contributions	'	'	431,680,000	'	'	'	'
Fair Value of Assets Acquired and Liabilities Assumed [Abstract]	'	'	'	'	'	'	'
Fair value of oil and natural gas properties	'	'	644,052,000	'	'	'	'
Asset retirement obligation	'	'	-1,063,000	'	'	'	'
Deferred tax liability	'	'	-211,309,000	'	'	'	'
Total net assets acquired	'	'	$431,680,000	'	'	'	'
Tax percentage used to estimate book to tax differences for oil and gas properties acquired	'	'	35.00%	'	'	'	'

Acquisitions_and_Sales_of_Oil_4

Acquisitions and Sales of Oil and Natural Gas Property Interests (ACTOIL NPI Repurchase) (Details) (USD $)	0 Months Ended		1 Months Ended	0 Months Ended	1 Months Ended
	Jan. 23, 2014	Sep. 10, 2013	Jul. 31, 2011	Jan. 23, 2014	Jul. 31, 2011
	ACTOIL NPI Repurchase [Member]	ACTOIL, LLC [Member]	ACTOIL, LLC [Member]	ACTOIL, LLC [Member]	ACTOIL, LLC [Member]
		Spanish Trail Acquisition [Member]	Spanish Trail Acquisition [Member]	IPO [Member]	ACTOIL NPI Repurchase [Member]
Significant Acquisitions and Disposals [Line Items]	'	'	'	'	'
Percentage of net profit interest transferred	'	25.00%	25.00%	25.00%	25.00%
Number of shares issued for ACTOIL NPI Repurchase	10,816,626	'	'	'	'
Value of the 10,816,626 shares of the Company’s common stock issued in the ACTOIL NPI Repurchase	$210,924,000	'	'	'	'
Elimination of NPI payable	-36,931,000	'	'	'	'
Oil and natural gas properties cost	158,115,000	'	'	'	'
Asset retirement obligation	-639,000	'	'	'	'
Deferred tax asset	16,517,000	'	'	'	'
Total consideration for the assets contributed in the ACTOIL NPI Repurchase	$173,993,000	'	'	'	'
Tax percentage used to estimate book to tax differences for oil and gas properties acquired	35.00%	'	'	'	'

Acquisitions_and_Sales_of_Oil_5

Acquisitions and Sales of Oil and Natural Gas Property Interests (Spanish Trail) (Details) (USD $)	0 Months Ended			0 Months Ended	1 Months Ended	0 Months Ended
	Jan. 23, 2014	Sep. 10, 2013	Sep. 10, 2013	Sep. 10, 2013	Jul. 31, 2011	Sep. 10, 2013
	IPO [Member]	Spanish Trail Acquisition [Member]	Spanish Trail Acquisition [Member]	Spanish Trail Acquisition [Member]	Spanish Trail Acquisition [Member]	Spanish Trail Acquisition [Member]
	ACTOIL, LLC [Member]		Term loan [Member]	ACTOIL, LLC [Member]	ACTOIL, LLC [Member]	IPO [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'
Net purchase price	'	$155,000,000	'	$120,521,000	'	$120,521,000
Percentage of net profit interest transferred	25.00%	'	'	25.00%	25.00%	'
25% NPI Sale to ACTOIL	'	-30,131,000	'	'	'	'
Oil and natural gas properties acquired	'	90,390,000	'	'	'	'
Asset retirement obligation assumed	'	296,000	'	'	'	'
Total net assets acquired	'	90,686,000	'	'	'	'
Term loan, face amount	'	'	$70,000,000	'	'	'

Acquisitions_and_Sales_of_Oil_6

Acquisitions and Sales of Oil and Natural Gas Property Interests (Resolute Sale) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Oct. 31, 2013	Dec. 31, 2013	Jun. 30, 2013	Oct. 02, 2012	Oct. 02, 2012	Oct. 02, 2012	Jun. 30, 2013	Oct. 02, 2012
			Sale of oil and natural gas properties [Member]	Sale of oil and natural gas properties [Member]	Sale of oil and natural gas properties [Member]	Sale of oil and natural gas properties [Member]	Sale of oil and natural gas properties [Member]	Sale of oil and natural gas properties [Member]	Sale of oil and natural gas properties [Member]	Sale of oil and natural gas properties [Member]
			escrow_payment				Title and environmental escrow [Member]	Indemnity escrow [Member]	RSP LLC, ACTOIL and other minority non-operating working interest owners [Member]	RSP LLC, ACTOIL and other minority non-operating working interest owners [Member]
Significant Acquisitions and Disposals [Line Items]	'	'	'	'	'	'	'	'	'	'
Interest in oil and natural gas assets sold (percent)	'	'	'	'	'	'	'	'	67.65%	32.35%
Sales price for interest in oil and natural gas properties	'	'	'	'	$144,200,000	$69,000,000	'	'	$230,000,000	$110,000,000
Option to acquire additional interests	'	'	'	'	'	2,400,000	'	'	'	5,000,000
Gain on sale of interest in oil and natural gas properties	'	'	'	22,700,000	6,000,000	6,700,000	'	'	'	'
Escrow held back from initial purchase price	17,000	15,000	'	'	'	'	5,000,000	11,000,000	'	'
Number of escrow payments received	'	'	2	'	'	'	'	'	'	'
Proceeds from collection of funds held in escrow	'	'	$12,000,000	'	'	'	'	'	'	'

Derivative_Instruments_Outstan

Derivative Instruments (Outstanding Positions) (Details)	6 Months Ended
	Jun. 30, 2014
	bbl
Crude Oil [Member] | Swaps Maturing in 2014 [Member]	'
Derivative [Line Items]	'
Notional volume (Bbl)	120,000
Weighted average price (in dollars per Bbl)	94.5
Crude Oil [Member] | Swaps Maturing in 2015 [Member]	'
Derivative [Line Items]	'
Notional volume (Bbl)	120,000
Weighted average price (in dollars per Bbl)	92.6
Crude Oil [Member] | Collars Maturing in 2014 [Member]	'
Derivative [Line Items]	'
Notional volume (Bbl)	975,000
Weighted average floor price (in dollars per Bbl/Mmbtu)	87.09
Weighted average ceiling price (in dollars per Bbl/Mmbtu)	100.75
Crude Oil [Member] | Collars Maturing in 2015 [Member]	'
Derivative [Line Items]	'
Notional volume (Bbl)	2,067,000
Weighted average floor price (in dollars per Bbl/Mmbtu)	86.7
Weighted average ceiling price (in dollars per Bbl/Mmbtu)	94.89
Natural Gas [Member] | Collars Maturing in 2014 [Member]	'
Derivative [Line Items]	'
Notional volume (Mmbtu)	750,000
Weighted average floor price (in dollars per Bbl/Mmbtu)	4
Weighted average ceiling price (in dollars per Bbl/Mmbtu)	4.78
Natural Gas [Member] | Collars Maturing in 2015 [Member]	'
Derivative [Line Items]	'
Notional volume (Mmbtu)	0
Weighted average floor price (in dollars per Bbl/Mmbtu)	0
Weighted average ceiling price (in dollars per Bbl/Mmbtu)	0

Derivative_Instruments_Gross_A

Derivative Instruments (Gross Assets and Liabilities) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Derivative assets	$3,730	$1,749
Derivative liabilities	-21,869	-1,605
Commodity contracts [Member] | Current amounts, Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative assets	1,629	671
Commodity contracts [Member] | Current amounts, Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative liabilities	-16,411	-1,562
Commodity contracts [Member] | Noncurrent amounts, Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative assets	2,101	1,078
Commodity contracts [Member] | Noncurrent amounts, Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative liabilities	($5,458)	($43)

Derivative_Instruments_Gain_Lo

Derivative Instruments (Gain Loss) (Details) (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]	'	'	'	'
Gain (loss) on derivative instruments	($15,958)	$922	($20,111)	($735)
Commodity derivative instruments [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Gain (loss) on derivative instruments	-15,958	934	-20,111	-719
Interest rate derivative instruments [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Gain (loss) on derivative instruments	$0	($12)	$0	($16)

Derivative_Instruments_Offsett

Derivative Instruments (Offsetting Assets and Liabilities) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Offsetting of Derivative Assets and Liabilities [Abstract]	'	'
Derivative asset, Gross Amount Presented on Balance Sheet	$3,730,000	$1,749,000
Derivative asset, Netting Adjustments	-3,730,000	-1,332,000
Derivative asset, Net Amount	0	417,000
Derivative liability, Gross Amount Presented on Balance Sheet	-21,869,000	-1,605,000
Derivative liability, Netting Adjustments	3,730,000	1,332,000
Derivative liability, Net Amount	-18,139,000	-273,000
Credit-Risk Related Contingent Features in Derivatives [Abstract]	'	'
Collateral posted for derivative instruments with credit-risk related contingent features	$0	$0

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (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]	'	'
Derivative liabilities	($21,869)	($1,605)
Derivative assets	3,730	1,749
Recurring basis [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative liabilities	-18,139	'
Derivative assets	'	144
Recurring basis [Member] | Commodity derivative instruments [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative liabilities	-18,139	'
Derivative assets	'	144
Recurring basis [Member] | Level 1 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative liabilities	0	'
Derivative assets	'	0
Recurring basis [Member] | Level 1 [Member] | Commodity derivative instruments [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative liabilities	0	'
Derivative assets	'	0
Recurring basis [Member] | Level 2 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative liabilities	-18,139	'
Derivative assets	'	144
Recurring basis [Member] | Level 2 [Member] | Commodity derivative instruments [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative liabilities	-18,139	'
Derivative assets	'	144
Recurring basis [Member] | Level 3 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative liabilities	0	'
Derivative assets	'	0
Recurring basis [Member] | Level 3 [Member] | Commodity derivative instruments [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative liabilities	0	'
Derivative assets	'	$0

Credit_Agreement_Details

Credit Agreement (Details) (USD $)	6 Months Ended
	Jun. 30, 2014	Jun. 09, 2014	Jun. 08, 2014	Sep. 10, 2013
				lender
				financial_ratio
Term loan [Member] | Spanish Trail Acquisition [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Term loan, face amount	'	'	'	$70,000,000
Revolving credit facility [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Number of lenders in syndicated bank group	'	'	'	11
Number of financial ratios	'	'	'	3
Working capital ratio, required	1	'	'	'
Minimum interest coverage ratio, required	3	'	'	'
Leverage ratio, required	4	'	'	'
Variable interest rate at period end	1.67%	'	'	'
Credit agreement, maximum borrowing capacity	375,000,000	375,000,000	300,000,000	500,000,000
Credit agreement, maximum borrowing capacity, lender commitments	$500,000,000	'	'	'
Revolving credit facility [Member] | Eurodollar [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Variable rate basis, base percentage prior to adjustments	100.00%	'	'	'
Revolving credit facility [Member] | Eurodollar [Member] | Minimum [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Basis spread on variable rate	1.25%	'	'	'
Revolving credit facility [Member] | Eurodollar [Member] | Maximum [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Basis spread on variable rate	2.00%	'	'	'
Revolving credit facility [Member] | Federal Funds Rate [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Basis spread on variable rate	1.00%	'	'	'
Revolving credit facility [Member] | Adjusted LIBOR rate [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Basis spread on variable rate	1.00%	'	'	'
Facility fee (percent)	0.50%	'	'	'
Revolving credit facility [Member] | Adjusted LIBOR rate [Member] | Minimum [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Interest rate terms, percentage of borrowing base utilized margin	0.25%	'	'	'
Revolving credit facility [Member] | Adjusted LIBOR rate [Member] | Maximum [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Interest rate terms, percentage of borrowing base utilized margin	1.00%	'	'	'

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	1 Months Ended	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Feb. 28, 2014	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'	'	'	'	'
Operating lease, term	'64 months	'	'	'	'
Rent expense	'	$78	$63	$161	$125

EquityBased_Compensation_Detai

Equity-Based Compensation (Details) (USD $)

3 Months Ended

6 Months Ended

1 Months Ended

3 Months Ended

6 Months Ended

1 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

In Millions, except Share data, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Restricted stock awards [Member]

Restricted stock awards [Member]

Performance-based restricted stock awards [Member]

Performance-based restricted stock awards [Member]

Performance-based restricted stock awards [Member]

Performance-based restricted stock awards [Member]

Performance-based restricted stock awards [Member]

Incentive units [Member]

Incentive units, Tier I and Tier IA [Member]

Incentive units, Tier I, Tier IA and Tier II [Member]

Incentive units, Tier I, Tier IA and Tier II [Member]

Incentive units, Tier IA and Tier II [Member]

Incentive units, Tier III and Tier IV [Member]

General and administrative expenses [Member]

General and administrative expenses [Member]

Minimum [Member]

Maximum [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based compensation expense

$1.30

$2.10

'

$0.10

$0.10

'

'

'

'

$0.20

$11.40

'

'

$1.70

$13.70

Unrecognized compensation expense

9

9

3.8

3.8

3.8

'

'

16.3

'

'

'

1.3

3.5

'

'

Unrecognized compensation expense, cost to be recognized during remainder of current year

'

'

'

'

'

'

'

'

'

'

'

0.5

'

'

'

Unrecognized compensation expense, cost to be recognized in next fiscal year

'

'

'

'

'

'

'

'

'

'

'

$0.80

'

'

'

Unrecognized compensation expense, weighted average recognition period

'

'2 years

'2 years 8 months 12 days

'

'

'

'

'

'

'

'

'

'

'

'

Award vesting period

'

'

'2 years 9 months

'

'

'

'

'

'3 years

'

'

'

'

'

'

Stock awards granted during the period (in shares)

'

'

134,400

'

'

'

'

'

'

'

'

'

'

'

'

Target payout percentage

'

'

100.00%

'

'

0.00%

200.00%

'

'

'

'

'

'

'

'

Restricted Shares, Outstanding [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted shares outstanding, beginning of period

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted shares granted

'

463,951

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted shares outstanding, end of period

463,951

463,951

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted Shares, Weighted Average Grant Price [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted shares outstanding, beginning of period, Weighted Average Grant Price (in dollars per share)

'

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted shares granted, Weighted Average Grant Price (in dollars per share)

'

$23.51

$28.14

'

'

'

'

'

'

'

'

'

'

'

'

Restricted shares outstanding, end of period, Weighted Average Grant Price (in dollars per share)

$23.51

$23.51

'

'

'

'

'

'

'

'

'

'

'

'

'

Earnings_Per_Share_Pro_Forma_E2

Earnings Per Share & Pro Forma Earnings Per Share (Details) (USD $)	3 Months Ended	6 Months Ended
In Thousands, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2014
Earnings Per Share [Abstract]	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	100,000	'
Numerator:	'	'
Income (loss) available to stockholders	$8,226	($119,303)
Basic net income (loss) allocable to participating securities (1)	49	0
Income (loss) available to stockholders	$8,177	($119,303)
Denominator:	'	'
Weighted average number of common shares outstanding - basic	72,500,000	67,702,000
Weighted average number of common shares outstanding - diluted (2)	72,500,000	67,702,000
Net income per share:	'	'
Basic (in dollars per share)	$0.11	($1.76)
Diluted (in dollars per share)	$0.11	($1.76)

Earnings_Per_Share_Pro_Forma_E3

Earnings Per Share & Pro Forma Earnings Per Share (Pro Forma) (Details) (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
Numerator:	'	'	'	'
Income before taxes, as reported	$13,174	$7,927	$20,859	$20,793
Pro forma provision for income taxes	'	'	7,509	'
Pro forma net income available to stockholders	'	'	13,350	'
Basic net income allocable to participating securities	'	'	82	'
Pro forma net income available to stockholders	'	'	$13,268	'
Denominator:	'	'	'	'
Weighted average number of common shares outstanding - basic	'	'	72,500	'
Weighted average number of common shares outstanding - diluted	'	'	72,500	'
Net income per share:	'	'	'	'
Basic (in dollars per share)	'	'	$0.18	'
Diluted (in dollars per share)	'	'	$0.18	'