Sanchez Energy (SNECQ) 10-Q 11 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Jun. 30, 2014	Aug. 08, 2014
Document and Entity Information	'	'
Entity Registrant Name	'Sanchez Energy Corp	'
Entity Central Index Key	'0001528837	'
Document Type	'10-Q	'
Document Period End Date	30-Jun-14	'
Amendment Flag	'false	'
Current Fiscal Year End Date	'--12-31	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	58,394,498
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$385,871	$153,531
Oil and natural gas receivables	56,456	51,960
Joint interest billing receivables	15,470	5,803
Fair value of derivative instruments	64	'
Deferred tax asset	18,471	6,882
Other current assets	5,893	1,386
Total current assets	482,225	219,562
Oil and natural gas properties, at cost, using the full cost method:	'	'
Unproved oil and natural gas properties	400,060	244,570
Proved oil and natural gas properties	2,051,312	1,297,961
Total oil and natural gas properties	2,451,372	1,542,531
Less: Accumulated depreciation, depletion, amortization and impairment	-288,258	-157,043
Total oil and natural gas properties, net	2,163,114	1,385,488
Other assets:	'	'
Debt issuance costs, net	45,157	19,806
Fair value of derivative instruments	108	1,304
Other assets	13,450	2,993
Total assets	2,704,054	1,629,153
Current liabilities:	'	'
Accounts payable	11,663	46,900
Accounts payable - related entities	1,888	961
Other payables	6,907	2,963
Accrued liabilities	123,552	102,455
Deferred premium liability	3,143	717
Fair value of derivative instruments	27,148	4,623
Total current liabilities	174,301	158,619
Long term debt, net of discount	1,443,710	593,258
Asset retirement obligations	22,626	4,130
Deferred tax liability	17,778	10,868
Deferred premium liability	2,465	4,891
Fair value of derivative instruments	9,421	78
Total liabilities	1,670,301	771,844
Commitments and contingencies (Note 15)	'	'
Stockholders' equity:	'	'
Preferred stock($0.01 par value, 15,000,000 shares authorized; 1,886,485 and 3,000,000 shares issued and outstanding as of June 30, 2014 and December 31, 2013 of 4.875% Convertible Perpetual Preferred Stock, Series A, respectively; 3,532,330 and 4,500,000 shares issued and outstanding as of June 30, 2014 and December 31, 2013 of 6.500% Convertible Perpetual Preferred Stock, Series B, respectively)	54	75
Common stock ($0.01 par value, 150,000,000 shares authorized; 58,125,398 and 46,368,713 shares issued and outstanding as of June 30, 2014 and December 31, 2013, respectively)	581	464
Additional paid-in capital	1,077,494	867,108
Accumulated deficit	-44,376	-10,338
Total stockholders' equity	1,033,753	857,309
Total liabilities and stockholders' equity	$2,704,054	$1,629,153

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Dec. 31, 2013
			Preferred stock, Convertible Perpetual Preferred Stock, Series A	Preferred stock, Convertible Perpetual Preferred Stock, Series A	Preferred stock, Convertible Perpetual Preferred Stock, Series B	Preferred stock, Convertible Perpetual Preferred Stock, Series B
Preferred stock, par value (in dollars per share)	'	'	$0.01	$0.01	$0.01	$0.01
Preferred stock, shares authorized	'	'	15,000,000	15,000,000	15,000,000	15,000,000
Dividend rate (as a percent)	'	'	4.88%	4.88%	6.50%	6.50%
Preferred stock, shares issued	'	'	1,886,485	3,000,000	3,532,330	4,500,000
Preferred stock, shares outstanding	'	'	1,886,485	3,000,000	3,532,330	4,500,000
Common stock, par value (in dollars per share)	$0.01	$0.01	'	'	'	'
Common stock, shares authorized	150,000,000	150,000,000	'	'	'	'
Common stock, shares issued	58,125,398	46,368,713	'	'	'	'
Common stock, shares outstanding	58,125,398	46,368,713	'	'	'	'

Condensed_Consolidated_Stateme

Condensed Consolidated Statements 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	$136,902	$54,872	$256,577	$84,199
Natural gas liquids sales	8,116	2,047	16,609	2,976
Natural gas sales	6,643	2,166	13,037	2,946
Total revenues	151,661	59,085	286,223	90,121
OPERATING COSTS AND EXPENSES:	'	'	'	'
Oil and natural gas production expenses	13,911	6,813	29,823	10,072
Production and ad valorem taxes	7,842	3,361	18,245	5,411
Depreciation, depletion, amortization and accretion	70,583	24,623	131,834	37,996
General and administrative (inclusive of stock-based compensation expense of $15,943 and $4,578, respectively, for the three months ended June 30, 2014 and 2013, and $25,878 and $7,712, respectively, for the six months ended June 30, 2014 and 2013)	28,869	12,632	48,178	20,369
Total operating costs and expenses	121,205	47,429	228,080	73,848
Operating income	30,456	11,656	58,143	16,273
Other income (expense):	'	'	'	'
Interest and other income	3	51	15	72
Interest expense	-17,261	-7,069	-30,533	-8,153
Net gains (losses) on commodity derivatives	-31,900	4,252	-41,017	624
Total other expense, net	-49,158	-2,766	-71,535	-7,457
Income (loss) before income taxes	-18,702	8,890	-13,392	8,816
Income tax benefit	-6,544	'	-4,679	'
Net income (loss)	-12,158	8,890	-8,713	8,816
Less:	'	'	'	'
Preferred stock dividends	-7,132	-5,484	-25,325	-7,556
Net income allocable to participating securities	'	-159	'	-56
Net income (loss) attributable to common stockholders	($19,290)	$3,247	($34,038)	$1,204
Net income (loss) per common share - basic and diluted (in dollars per share)	($0.38)	$0.10	($0.70)	$0.04
Weighted average number of shares used to calculate net income (loss) attributable to common stockholders - basic and diluted (in shares)	50,602	33,117	48,825	33,108

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Operations (Parenthetical) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Condensed Consolidated Statements of Operations	'	'	'	'
General and administrative, stock-based compensation expense (in dollars)	$15,943	$4,578	$25,878	$7,712

Condensed_Consolidated_Stateme2

Condensed Consolidated Statement of Stockholders' Equity (USD $)	Total	Common Stock	Additional Paid-in Capital	Accumulated Deficit	Series A Preferred Stock	Series B Preferred Stock
In Thousands, except Share data, unless otherwise specified
BALANCE at Dec. 31, 2013	$857,309	$464	$867,108	($10,338)	$30	$45
BALANCE (in shares) at Dec. 31, 2013	'	46,369,000	'	'	3,000,000	4,500,000
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'	'
Common shares issued	167,591	50	167,541	'	'	'
Common shares issued (in shares)	'	5,000,000	'	'	'	'
Preferred stock dividends	-8,312	'	'	-8,312	'	'
Restricted stock awards, net of forfeitures	'	13	-13	'	'	'
Restricted stock awards, net of forfeitures (in shares)	'	1,337,000	'	'	'	'
Exchange of preferred stock for common stock	'	54	16,980	-17,013	-11	-10
Exchange of preferred stock for common stock (in shares)	'	5,419,000	'	'	-1,113,000	-968,000
Stock-based compensation	25,878	'	25,878	'	'	'
Net loss	-8,713	'	'	-8,713	'	'
BALANCE at Jun. 30, 2014	$1,033,753	$581	$1,077,494	($44,376)	$19	$35
BALANCE (in shares) at Jun. 30, 2014	'	58,125,000	'	'	1,887,000	3,532,000

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements 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)	($8,713)	$8,816
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation, depletion, amortization and accretion	131,834	37,996
Stock-based compensation	25,878	7,712
Net (gains) losses on commodity derivative contracts	41,017	-624
Net cash settlement received (paid) on commodity derivative contracts	-6,057	141
Premiums paid on derivative contracts	'	-189
Amortization of deferred financing costs	5,505	4,600
Accretion of debt discount	452	'
Deferred taxes	-4,679	'
Changes in operating assets and liabilities:	'	'
Accounts receivable	-14,163	-14,360
Other assets	-5,894	-361
Accounts payable	-35,237	25,811
Accounts payable - related entities	927	-12,891
Other payables	2,174	3,855
Accrued liabilities	8,991	8,335
Net cash provided by operating activities	142,035	68,841
CASH FLOWS FROM INVESTING ACTIVITIES:	'	'
Payments for oil and natural gas properties	-328,673	-175,213
Payments for other property and equipment	-7,065	-1,523
Acquisitions of oil and natural gas properties	-552,380	-291,890
Purchases of investments	'	-25,000
Sale of investments	'	11,591
Net cash used in investing activities	-888,118	-482,035
CASH FLOWS FROM FINANCING ACTIVITIES:	'	'
Proceeds from borrowings	100,000	236,000
Repayment of borrowings	-100,000	-236,000
Issuance of senior notes	850,000	400,000
Issuance of common stock	176,250	'
Issuance of preferred stock	'	225,000
Payments for offering costs	-8,659	-8,439
Financing costs	-30,856	-18,476
Preferred dividends paid	-8,312	-7,556
Purchase of common stock	'	-1,040
Net cash provided by financing activities	978,423	589,489
Increase in cash and cash equivalents	232,340	176,295
Cash and cash equivalents, beginning of period	153,531	50,347
Cash and cash equivalents, end of period	385,871	226,642
NON-CASH INVESTING AND FINANCING ACTIVITIES:	'	'
Asset retirement obligations	18,229	2,318
Change in accrued capital expenditures	12,106	7,775
Common stock issued in exchange for preferred stock	121,072	'
SUPPLEMENTAL DISCLOSURE:	'	'
Cash paid for interest	$25,029	$2,020

Organization

Organization	6 Months Ended
	Jun. 30, 2014
Organization	'
Organization	'
	Note 1. Organization
	Sanchez Energy Corporation (together with our consolidated subsidiaries, the "Company," "we," "our," "us" or similar terms) is an independent exploration and production company, formed in August 2011 as a Delaware corporation, focused on the exploration, acquisition and development of unconventional oil and natural gas resources in the onshore U.S. Gulf Coast, with a current focus on the Eagle Ford Shale in South Texas and the Tuscaloosa Marine Shale ("TMS") in Mississippi and Louisiana. We have accumulated net leasehold acreage in the oil and condensate, or black oil and volatile oil, windows of the Eagle Ford Shale and in what we believe to be the core of the TMS. We are currently focused on the horizontal development of significant resource potential from the Eagle Ford Shale.

Basis_of_Presentation_and_Summ

Basis of Presentation and Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2014
Basis of Presentation and Summary of Significant Accounting Policies	'
Basis of Presentation and Summary of Significant Accounting Policies	'
	Note 2. Basis of Presentation and Summary of Significant Accounting Policies
	The accompanying condensed consolidated financial statements are unaudited and were prepared from the Company's records. The condensed consolidated financial statements were prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP" or "U.S. GAAP") for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. The Company derived the condensed consolidated balance sheet as of December 31, 2013 from the audited financial statements filed in its Annual Report on Form 10-K for the fiscal year ended December 31, 2013 (the "2013 Annual Report"). Because this is an interim period filing presented using a condensed format, it does not include all of the disclosures required by U.S. GAAP. These condensed consolidated financial statements should be read in connection with the consolidated financial statements and notes thereto included in the 2013 Annual Report, which contains a summary of the Company's significant accounting policies and other disclosures. In the opinion of management, these financial statements include the adjustments and accruals, all of which are of a normal recurring nature, which are necessary for a fair presentation of the results for the interim periods. These interim results are not necessarily indicative of results to be expected for the entire year.
	As of June 30, 2014, the Company's significant accounting policies are consistent with those discussed in Note 2 in the notes to the Company's consolidated financial statements contained in its 2013 Annual Report.
	Use of Estimates
	The condensed consolidated financial statements are prepared in conformity with U.S. GAAP, which requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The most significant estimates pertain to proved oil and natural gas reserves and related cash flow estimates used in the calculation of depletion and impairment of oil and natural gas properties, fair value accounting for acquisitions, the evaluation of unproved properties for impairment, the fair value of commodity derivative contracts and asset retirement obligations, accrued oil and natural gas revenues and expenses and the allocation of general and administrative expenses. Actual results could differ materially from those estimates.
	Recent Accounting Pronouncements
	In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers ("ASU 2014-09"), which supersedes nearly all existing revenue recognition guidance under U.S. GAAP. The core principle of ASU 2014-09 is to recognize revenues when promised goods or services are transferred to customers in an amount that reflects the consideration to which an entity expects to be entitled for those goods or services. ASU 2014-09 defines a five step process to achieve this core principle and, in doing so, more judgment and estimates may be required within the revenue recognition process than are required under existing U.S. GAAP.
	The standard is effective for annual periods beginning after December 15, 2016, and interim periods therein, using either of the following transition methods: (i) a full retrospective approach reflecting the application of the standard in each prior reporting period with the option to elect certain practical expedients, or (ii) a retrospective approach with the cumulative effect of initially adopting ASU 2014-09 recognized at the date of adoption (which includes additional footnote disclosures). We are currently evaluating the impact of our pending adoption of ASU 2014-09 on our consolidated financial statements and have not yet determined the method by which we will adopt the standard in 2017.

Acquisitions

Acquisitions	6 Months Ended
	Jun. 30, 2014
Acquisitions	'
Acquisitions	'
	Note 3. Acquisitions
	Our acquisitions are accounted for under the acquisition method of accounting in accordance with Accounting Standards Codification, or ASC, Topic 805, "Business Combinations." A business combination may result in the recognition of a gain or goodwill based on the measurement of the fair value of the assets acquired at the acquisition date as compared to the fair value of consideration transferred, adjusted for purchase price adjustments. The initial accounting for acquisitions may not be complete and adjustments to provisional amounts, or recognition of additional assets acquired or liabilities assumed, may occur as more detailed analyses are completed and additional information is obtained about the facts and circumstances that existed as of the acquisition dates. The results of operations of the properties acquired in our acquisitions have been included in the condensed consolidated financial statements since the closing dates of the acquisitions.
	Catarina Acquisition
	On June 30, 2014, we completed our acquisition of the Catarina properties (the "Catarina acquisition") for an aggregate adjusted purchase price of $553.5 million. The effective date of the transaction was January 1, 2014. The purchase price was funded with proceeds from the issuance of the $850 million senior unsecured 6.125% notes due 2023 and cash on hand. The purchase price allocation for the Catarina acquisition is preliminary and is subject to further adjustments and the settlement of certain post-closing adjustments with the seller. The total purchase price was allocated to the assets purchased and liabilities assumed based upon their fair values on the date of acquisition as follows (in thousands):
	Proved oil and natural gas properties	$	428,484
	Unproved properties		137,089
	Other assets acquired		2,682
	Fair value of assets acquired		568,255
	Asset retirement obligations		(14,723	)
	Fair value of net assets acquired	$	553,532
	Cotulla Acquisition
	On May 31, 2013, we completed our acquisition of the Cotulla properties (the "Cotulla acquisition") for an aggregate adjusted purchase price of $280.9 million. The effective date of the transaction was March 1, 2013.
	The purchase price was funded with borrowings under the Company's First Lien Credit Agreement (defined in Note 6 "Long-Term Debt"), cash on hand, and proceeds from the Company's private placement of the Series B Convertible Perpetual Preferred Stock. The total purchase price was allocated to the assets purchased and liabilities assumed based upon their fair values on the date of acquisition as follows (in thousands):
	Proved oil and natural gas properties	$	265,466
	Unproved properties		16,745
	Fair value of assets acquired		282,211
	Asset retirement obligations		(1,138	)
	Other liabilities assumed		(190	)
	Fair value of net assets acquired	$	280,883
	Wycross Acquisition
	On October 4, 2013, we completed our acquisition of the Wycross properties (the "Wycross acquisition") for an aggregate adjusted purchase price of $229.6 million. The effective date of the transaction was July 1, 2013. The purchase price was funded with proceeds from the issuance of the Additional Notes (defined in Note 6 "Long-Term Debt"), the issuance of 11,040,000 shares of common stock, and cash on hand. The total purchase price was allocated to the assets purchased and liabilities assumed based upon their fair values on the date of acquisition as follows (in thousands):
	Proved oil and natural gas properties	$	215,265
	Unproved properties		13,095
	Other assets acquired		1,523
	Fair value of assets acquired		229,883
	Asset retirement obligations		(158	)
	Other liabilities assumed		(113	)
	Fair value of net assets acquired	$	229,612
	Pro Forma Operating Results
	The following pro forma combined results for the three and six months ended June 30, 2014 and 2013 reflect the consolidated results of operations of the Company as if the Catarina acquisition and related financing had occurred on January 1, 2013 and the Wycross and Cotulla acquisitions and related financings had occurred on January 1, 2012. The pro forma information includes adjustments primarily for revenues and expenses from the acquired properties, depreciation, depletion, amortization and accretion, interest expense and debt issuance cost amortization for acquisition debt, and stock dividends for the issuance of preferred stock.
	The unaudited pro forma combined financial statements give effect to the events set forth below:
	•
	The Catarina acquisition completed on June 30, 2014.
	•
	Issuance of the 6.125% Notes (defined in Note 6 "Long-Term Debt") to finance a portion of the Catarina acquisition, and the related adjustments to interest expense.
	•
	The Cotulla acquisition completed on May 31, 2013.
	•
	The increase in borrowings under the First Lien Credit Agreement to finance a portion of the Cotulla acquisition, and the related adjustments to interest expense.
	•
	Issuance of Series B Convertible Perpetual Preferred Stock and related adjustments to preferred dividends.
	•
	The Wycross acquisition completed on October 4, 2013.
	•
	Issuance of the 7.75% Notes (defined in Note 6 "Long-Term Debt") to finance a portion of the Wycross acquisition, and the related adjustments to interest expense.
	•
	Issuance of common stock to finance a portion of the Wycross acquisition and the related effect on net income (loss) per common share (in thousands, except per share amounts).
		Three Months Ended					Six Months Ended
		June 30,					June 30,
		2014			2013		2014			2013
	Revenues	$	216,051		$	190,468	$	445,563		$	347,865
	Net income (loss) attributable to common stockholders	$	(12,268	)	$	12,498	$	(7,920	)	$	11,028
	Net income (loss) per common share, basic	$	(0.24	)	$	0.36	$	(0.16	)	$	0.32
	Net income (loss) per common share, diluted	$	(0.24	)	$	0.34	$	(0.16	)	$	0.32
	The pro forma combined financial information is for informational purposes only and is not intended to represent or to be indicative of the combined results of operations that the Company would have reported had the Catarina, Wycross and Cotulla acquisitions and related financings been completed as of the date set forth in this pro forma combined financial information and should not be taken as indicative of the Company's future combined results of operations. The actual results may differ significantly from that reflected in the pro forma combined financial information for a number of reasons, including, but not limited to, differences in assumptions used to prepare the pro forma combined financial information and actual results.
	Post-Acquisition Operating Results
	The amounts of revenue and excess of revenues over direct operating expenses included in the Company's condensed consolidated statements of operations for the three and six months ended June 30, 2014 and 2013, for the Wycross and Cotulla acquisitions are shown in the table that follows. Direct operating expenses include lease operating expenses and production and ad valorem taxes (in thousands):
		Three Months Ended					Six Months Ended
		June 30,					June 30,
		2014			2013		2014			2013
	Revenues	$	54,937		$	8,474	$	109,408		$	8,474
	Excess of revenues over direct operating expenses	$	45,136		$	4,929	$	86,505		$	4,929

Cash_and_Cash_Equivalents

Cash and Cash Equivalents	6 Months Ended
	Jun. 30, 2014
Cash and Cash Equivalents	'
Cash and Cash Equivalents	'
	Note 4. Cash and Cash Equivalents
	As of June 30, 2014 and December 31, 2013, cash and cash equivalents consisted of the following (in thousands):
		June 30,		December 31,
		2014		2013
	Cash at banks	$	135,870	$	48,326
	Money market funds		250,001		105,205
	Total cash and cash equivalents	$	385,871	$	153,531

Oil_and_Natural_Gas_Properties

Oil and Natural Gas Properties	6 Months Ended
	Jun. 30, 2014
Oil and Natural Gas Properties	'
Oil and Natural Gas Properties	'
	Note 5. Oil and Natural Gas Properties
	The Company's oil and natural gas properties are accounted for using the full cost method of accounting. All direct costs and certain indirect costs associated with the acquisition, exploration and development of oil and natural gas properties are capitalized. Once evaluated, these costs, as well as the estimated costs to retire the assets, are included in the amortization base and amortized to depletion expense using the units-of-production method. Depletion is calculated based on estimated proved oil and natural gas reserves. Proceeds from the sale or disposition of oil and natural gas properties are applied to reduce net capitalized costs unless the sale or disposition causes a significant change in the relationship between costs and the estimated quantity of proved reserves.
	Full Cost Ceiling Test—Capitalized costs (net of accumulated depreciation, depletion and amortization and deferred income taxes) of proved oil and natural gas properties are subject to a full cost ceiling limitation. The ceiling limits these costs to an amount equal to the present value, discounted at 10%, of estimated future net cash flows from estimated proved reserves less estimated future operating and development costs, abandonment costs (net of salvage value) and estimated related future income taxes. In accordance with SEC rules, the oil and natural gas prices used to calculate the full cost ceiling are the 12-month average prices, calculated as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month period prior to the end of the reporting period, unless prices are defined by contractual arrangements. Prices are adjusted for "basis" or location differentials. Prices are held constant over the life of the reserves. If unamortized costs capitalized within the cost pool exceed the ceiling, the excess is charged to expense and separately disclosed during the period in which the excess occurs. Amounts thus required to be written off are not reinstated for any subsequent increase in the cost center ceiling. No impairment expense was recorded for the three and six month periods ended June 30, 2014 or 2013.
	Investments in unproved properties and major development projects are capitalized and excluded from the amortization base until proved reserves associated with the projects can be determined or until impairment occurs. Once the assessment of unproved properties is complete and when major development projects are evaluated, the costs previously excluded from amortization are transferred to the full cost pool subject to periodic amortization. The Company assesses the carrying value of its unproved properties that are not subject to amortization for impairment periodically. If the results of an assessment indicate that the properties are impaired, the amount of the asset impaired is added to the full cost pool subject to both periodic amortization and the ceiling test.

LongTerm_Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2014
Long-Term Debt	'
Long-Term Debt	'
	Note 6. Long-Term Debt
	Long-term debt on June 30, 2014 consisted of $850 million principal amount of 6.125% senior notes maturing on January 15, 2023 (the "6.125% Notes") and $600 million principal amount of 7.75% senior notes (the "7.75% Notes" and, together with the 6.125% Notes, the "Senior Notes") which were issued at a discount to face value of $7.0 million, maturing on June 15, 2021. As of June 30, 2014, the Company's long-term debt consisted of the following:
		Interest Rate	Maturity date	Amount
				Outstanding
				(in thousands)
	Second amended and restated credit agreement	Variable	June 30, 2019	$	—
	7.75% Notes	7.75%	June 15, 2021		600,000
	6.125% Notes	6.13%	January 15, 2023		850,000
					1,450,000
	Unamortized discount on Senior Notes				(6,290	)
	Total long-term debt			$	1,443,710
	Credit Facility
	Previous Credit Agreement:    On May 31, 2013, we and our subsidiaries, SEP Holdings III, LLC ("SEP III"), SN Marquis LLC ("SN Marquis") and SN Cotulla Assets, LLC ("SN Cotulla") collectively, as the borrowers, entered into a revolving credit facility which was represented by a $500 million Amended and Restated Credit Agreement with Royal Bank of Canada as the administrative agent, Capital One, National Association as the syndication agent and RBC Capital Markets as sole lead arranger and sole book runner and each of the other lenders party thereto ("First Lien Credit Agreement"). The First Lien Credit Agreement was to mature on May 31, 2018.
	On May 12, 2014, the Company borrowed $100 million under the First Lien Credit Agreement. The Company used proceeds from the issuance of the 6.125% Notes to repay the $100 million outstanding.
	Second Amended and Restated Credit Agreement:    On June 30, 2014, the Company, as borrower, and SEP III, SN Marquis, SN Cotulla, SN Operating, LLC, SN TMS, LLC and SN Catarina, LLC as loan parties, entered into a revolving credit facility represented by a $1.5 billion Second Amended and Restated Credit Agreement, dated June 30, 2014, with Royal Bank of Canada as the administrative agent, Capital One, National Association as the syndication agent, Compass Bank and SunTrust Bank as co-documentation agents, RBC Capital Markets as sole lead arranger and sole book runner and the lenders party thereto (the "Credit Agreement"). The Company has elected an available commitment amount under the Credit Agreement of $425 million. Additionally, the Credit Agreement provides for the issuance of letters of credit, limited in the aggregate to the lesser of $50 million and the total availability thereunder. As of June 30, 2014, there were no borrowings and no letters of credit outstanding under the Credit Agreement. Availability under the Credit Agreement is at all times subject to customary conditions and the then applicable borrowing base. The borrowing base under the Company's Credit Agreement was set at $437.5 million upon issuance of the 6.125% Notes and completion of the Catarina acquisition, with an elected commitment amount of $425 million, all of which was available for future revolver borrowings as of June 30, 2014.
	The Credit Agreement matures on June 30, 2019. The borrowing base under the Credit Agreement can be subsequently redetermined up or down by the lenders based on, among other things, their evaluation of the Company's and its subsidiaries' oil and natural gas reserves. Redeterminations of the borrowing base are scheduled to occur semi-annually on April 1 and October 1 of each year, beginning on October 1, 2014. The borrowing base is also subject to reduction by 25% of the amount of the increase in the Company's net high yield debt resulting from the issuance of high yield debt.
	The Company's obligations under the Credit Agreement are secured by a first priority lien on substantially all of its assets and the assets of the Company's existing and future subsidiaries not designated as "unrestricted subsidiaries," including a first priority lien on all ownership interests in existing and future subsidiaries not designated as "unrestricted subsidiaries." The obligations under the Credit Agreement are guaranteed by all of the Company's existing and future subsidiaries not designated as "unrestricted subsidiaries."
	At the Company's election, borrowings under the Credit Agreement may be made on an alternate base rate or an adjusted eurodollar rate basis, plus an applicable margin. The applicable margin varies from 0.50% to 1.50% for alternate base rate borrowings and from 1.50% to 2.50% for eurodollar borrowings, depending on the utilization of the borrowing base. Furthermore, the Company is also required to pay a commitment fee on the unused committed amount at a rate varying from 0.375% to 0.50% per annum, depending on the utilization of the borrowing base.
	The Credit Agreement contains various affirmative and negative covenants and events of default that limit the Company's ability to, among other things, incur indebtedness, make restricted payments, grant liens, consolidate or merge, dispose of certain assets, make certain investments, engage in transactions with affiliates, hedge transactions and make certain acquisitions. The Credit Agreement also provides for cross default between the Credit Agreement and the Company's senior unsecured notes. Furthermore, the Credit Agreement contains financial covenants that require the Company to satisfy certain specified financial ratios, including (i) current assets to current liabilities of at least 1.0 to 1.0 at all times, commencing with the fiscal quarter ending September 30, 2014 and (ii) net debt to consolidated EBITDA of not greater than 4.0 to 1.0 as of the last day of any fiscal quarter, commencing with the fiscal quarter ending September 30, 2014.
	From time to time, the agents, arrangers, book runners and lenders under the Credit Agreement and their affiliates have provided, and may provide in the future, investment banking, commercial lending, hedging and financial advisory services to the Company and its affiliates in the ordinary course of business, for which they have received, or may in the future receive, customary fees and commissions for these transactions. As of June 30, 2014, the Company was in compliance with the covenants of the Credit Agreement.
	Bridge Commitment:    In connection with the Catarina acquisition we obtained a commitment (the "Bridge Commitment") from Royal Bank of Canada, RBC Capital Markets, Credit Suisse AG, Credit Suisse Securities (USA) LLC, Capital One, National Association and SunTrust Bank to provide, arrange, bookrun and agent, as applicable, a senior unsecured bridge facility (the "Bridge Facility"), in an aggregate amount up to $300 million (reduced by the aggregate principal amount of notes issued and sold pursuant to this offering). The Bridge Commitment was set to expire upon the earliest to occur of (a) August 19, 2014, (b) the date of execution and delivery of definitive bridge documentation by us and the lenders under the Bridge Facility or (c) the termination of the commitments by us. The Company terminated the Bridge Commitment upon the execution of the Credit Agreement on June 30, 2014 and wrote off $3.9 million in costs associated with obtaining the Bridge Commitment to interest expense at that time.
	7.75% Senior Notes Due 2021
	On June 13, 2013, we completed a private offering of $400 million in aggregate principal amount of our 7.75% senior notes that will mature on June 15, 2021 (the "Original Notes"). Interest is payable on each June 15 and December 15. We received net proceeds from this offering of approximately $388 million, after deducting initial purchasers' discounts and offering expenses, which we used to repay outstanding indebtedness under our credit facilities. The Original Notes are senior unsecured obligations and are guaranteed on a joint and several senior unsecured basis by, with certain exceptions, substantially all of our existing and future subsidiaries. The borrowing base under our revolving credit facility was reduced to $87.5 million upon issuance of the Original Notes, and was later increased to $400 million.
	On September 18, 2013, we issued an additional $200 million in aggregate principal amount of our 7.75% senior notes due 2021 (the "Additional Notes" and, together with the Original Notes, the "7.75% Notes") in a private offering at a price to the purchasers of 96.5% of the Additional Notes. We received net proceeds from this offering of $188.8 million, after deducting the initial purchasers' discounts and estimated offering expenses of $4.2 million. The Additional Notes were issued under the same indenture as the original notes, and are therefore treated as a single class of securities under the indenture. We used the net proceeds from the offering to partially fund the Wycross acquisition completed in October 2013, a portion of the 2013 and 2014 capital budgets, and and for general corporate purposes.
	The 7.75% Notes are senior unsecured obligations and rank equally in right of payment with all of our existing and future senior unsecured indebtedness. The 7.75% Notes rank senior in right of payment to our future subordinated indebtedness. The 7.75% Notes are effectively junior in right of payment to all of our existing and future secured debt (including under our credit facility) to the extent of the value of the assets securing such debt. The 7.75% Notes are fully and unconditionally guaranteed on a joint and several senior unsecured basis by the subsidiary guarantors party to the indenture governing the 7.75% Notes. To the extent set forth in the indenture governing the 7.75% Notes, certain of our subsidiaries will be required to fully and unconditionally guarantee the 7.75% Notes on a joint and several senior unsecured basis in the future.
	The indenture governing the 7.75% Notes, among other things, restricts our ability and our restricted subsidiaries' ability to: (i) incur additional indebtedness or issue preferred stock; (ii) pay dividends or make other distributions; (iii) make other restricted payments and investments; (iv) create liens on their assets; (v) incur restrictions on the ability of restricted subsidiaries to pay dividends or make certain other payments; (vi) sell assets, including capital stock of restricted subsidiaries; (vii) merge or consolidate with other entities; and (viii) enter into transactions with affiliates.
	We have the option to redeem all or a portion of the 7.75% Notes, at any time on or after June 15, 2017 at the applicable redemption prices specified in the indenture plus accrued and unpaid interest. We may also redeem the 7.75% Notes, in whole or in part, at a redemption price equal to 100% of their principal amount plus a make whole premium, together with accrued and unpaid interest and additional interest, if any, to the redemption date, at any time prior to June 15, 2017. In addition, we may redeem up to 35% of the 7.75% Notes prior to June 15, 2016 under certain circumstances with an amount equal to the net cash proceeds from one or more equity offerings at the redemption price specified in the indenture. We may also be required to repurchase the 7.75% Notes upon a change of control or if we sell certain of our assets.
	6.125% Senior Notes Due 2023
	On June 27, 2014, the Company completed a private offering to eligible purchasers of $850 million in aggregate principal amount of the Company's 6.125% Notes. Interest is payable on each July 15 and January 15. The Company received net proceeds from this offering of approximately $829 million, after deducting initial purchasers' discounts and estimated offering expenses, which the Company used to repay all of the $100 million in borrowings outstanding under its First Lien Credit Agreement and to finance a portion of the purchase price of the Catarina acquisition. We intend to use the remaining proceeds from the offering to fund a portion of the remaining 2014 capital budget and for general corporate purposes. The 6.125% Notes are the senior unsecured obligations of the Company and are guaranteed on a joint and several senior unsecured basis by, with certain exceptions, substantially all of the Company's existing and future subsidiaries.
	The 6.125% Notes are the senior unsecured obligations of the Company and rank equally in right of payment with all of the Company's existing and future senior unsecured indebtedness. The 6.125% Notes rank senior in right of payment to the Company's future subordinated indebtedness. The 6.125% Notes are effectively junior in right of payment to all of the Company's existing and future secured debt (including under the First Lien Credit Agreement) to the extent of the value of the assets securing such debt. The 6.125% Notes are fully and unconditionally guaranteed on a joint and several senior unsecured basis by the subsidiary guarantors party to the indenture governing the 6.125% Notes. To the extent set forth in the indenture governing the 6.125% Notes, certain subsidiaries of the Company will be required to fully and unconditionally guarantee the 6.125% Notes on a joint and several senior unsecured basis in the future.
	The indenture governing the 6.125% Notes, among other things, restricts the Company's ability and the ability of the Company's restricted subsidiaries to: (i) incur, assume or guarantee additional indebtedness or issue certain types of equity securities; (ii) pay distributions on, purchase or redeem shares or purchase or redeem subordinated debt; (iii) make certain investments; (iv) enter into certain transactions with affiliates; (v) create or incur liens on their assets; (vi) sell assets; (vii) consolidate, merge or transfer all or substantially all of their assets; (viii) restrict distributions or other payments from the Company's restricted subsidiaries; and (ix) designate subsidiaries as unrestricted subsidiaries.
	The Company has the option to redeem all or a portion of the 6.125% Notes, at any time on or after July 15, 2018 at the applicable redemption prices specified in the indenture plus accrued and unpaid interest. The Company may also redeem the 6.125% Notes, in whole or in part, at a redemption price equal to 100% of their principal amount plus a make whole premium, together with accrued and unpaid interest and additional interest, if any, to the redemption date, at any time prior to July 15, 2018. In addition, the Company may redeem up to 35% of the 6.125% Notes prior to July 15, 2017 under certain circumstances with the net cash proceeds from certain equity offerings at the redemption price specified in the indenture. The Company may also be required to repurchase the 6.125% Notes upon a change of control.

Derivative_Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2014
Derivative Instruments	'
Derivative Instruments	'
	Note 7. Derivative Instruments
	To reduce the impact of fluctuations in oil and natural gas prices on the Company's revenues, or to protect the economics of property acquisitions, the Company periodically enters into derivative contracts with respect to a portion of its projected oil and natural gas production through various transactions that fix or, through options, modify the future prices to be realized. These transactions may include price swaps whereby the Company will receive a fixed price for its production and pay a variable market price to the contract counterparty. Additionally, the Company may enter into collars, whereby it receives the excess, if any, of the fixed floor over the floating rate or pays the excess, if any, of the floating rate over the fixed ceiling price. In addition, the Company enters into option transactions, such as puts or put spreads, as a way to manage its exposure to fluctuating prices. These hedging activities are intended to support oil and natural gas prices at targeted levels and to manage exposure to oil and natural gas price fluctuations. It is never the Company's intention to enter into derivative contracts for speculative trading purposes.
	Under ASC Topic 815, "Derivatives and Hedging," all derivative instruments are recorded on the condensed consolidated balance sheets at fair value as either short-term or long-term assets or liabilities based on their anticipated settlement date. The Company will net derivative assets and liabilities for counterparties where it has a legal right of offset. Changes in the derivatives' fair values are recognized currently in earnings since the Company has elected not to designate its current derivative contracts as hedges.
	As of June 30, 2014, the Company had the following crude oil swaps, collars, and put spreads covering anticipated future production:
	Contract Period	Derivative		Barrels			Purchased			Sold			Pricing Index
		Instrument
	July 1, 2014 - December 31, 2014	Swap			138,000		$	92			n/a		NYMEX WTI
	July 1, 2014 - December 31, 2014	Swap			138,000		$	91.35			n/a		NYMEX WTI
	July 1, 2014 - December 31, 2014	Swap			138,000		$	92.45			n/a		NYMEX WTI
	July 1, 2014 - December 31, 2014	Swap			184,000		$	95.45			n/a		NYMEX WTI
	July 1, 2014 - December 31, 2014	Swap			184,000		$	93.25			n/a		NYMEX WTI
	January 1, 2015 - December 31, 2015	Swap			365,000		$	89.65			n/a		NYMEX WTI
	January 1, 2015 - December 31, 2015	Swap			365,000		$	90.05			n/a		NYMEX WTI
	January 1, 2015 - December 31, 2015	Swap			365,000		$	88.48			n/a		NYMEX WTI
	January 1, 2015 - December 31, 2015	Swap			365,000		$	88.35			n/a		NYMEX WTI
	July 1, 2014 - December 31, 2014	Collar			184,000		$	90		$	99.1		NYMEX WTI
	July 1, 2014 - December 31, 2014	Put Spread			184,000		$	90		$	75		NYMEX WTI
	As of June 30, 2014, the Company had the following crude oil enhanced swaps covering anticipated future production:
	Contract Period	Barrels			Purchased			Put			Pricing Index
	January 1, 2015 - December 31, 2015		365,000		$	91.46		$	75		NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000		$	93.13		$	75		NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000		$	92.2		$	75		NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000		$	91.46		$	75		NYMEX WTI
	As of June 30, 2014, the Company had the following natural gas swaps and collars covering anticipated future production:
	Contract Period	Derivative		Mmbtu			Purchased			Sold			Pricing Index
		Instrument
	July 1, 2014 - December 31, 2014	Swap			368,000		$	4.23			n/a		NYMEX NG
	July 1, 2014 - December 31, 2014	Swap			368,000		$	4.23			n/a		NYMEX NG
	July 1, 2014 - December 31, 2014	Swap			368,000		$	4.24			n/a		NYMEX NG
	July 1, 2014 - December 31, 2014	Swap			368,000		$	4.61			n/a		NYMEX NG
	July 1, 2014 - December 31, 2014	Collar			368,000		$	4		$	4.5		NYMEX NG
	As of June 30, 2014, the Company had the following natural gas enhanced swaps covering anticipated future production:
	Contract Period	Mmbtu			Purchased			Put			Pricing Index
	January 1, 2015 - December 31, 2015		2,190,000		$	4.44		$	3.75		NYMEX NG
	January 1, 2015 - December 31, 2015		1,095,000		$	4.4		$	3.75		NYMEX NG
	January 1, 2015 - December 31, 2015		730,000		$	4.5		$	3.75		NYMEX NG
	As of June 30, 2014, the Company had the following three-way crude oil collar contracts that combine a long and short put with a short call:
	Contract Period	Barrels			Short Put			Long Put			Short Call			Pricing Index
	July 1, 2014 - December 31, 2014		276,000		$	65		$	85		$	102.25		NYMEX WTI
	July 1, 2014 - December 31, 2014		184,000		$	75		$	95		$	107.5		LLS
	July 1, 2014 - December 31, 2014		184,000		$	75		$	90		$	96.22		NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000		$	70		$	85		$	95		NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000		$	70		$	85		$	95		NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000		$	70		$	85		$	94.75		NYMEX WTI
	The Company deferred the payment of premiums associated with certain of its oil derivative instruments. On June 30, 2014 and December 31, 2013, the balances of deferred payments totaled $5.6 million. These premiums are being paid to the counterparty with each monthly settlement beginning July 2014.
	The following table sets forth a reconciliation of the changes in fair value of the Company's commodity derivatives for the six months ended June 30, 2014 and the year ended December 31, 2013 (in thousands):
		June 30, 2014			December 31, 2013
	Beginning fair value of commodity derviatives	$	(3,397	)	$	2,145
	Net losses on crude oil derivatives		(40,323	)		(16,891	)
	Net losses on natural gas derivatives		(694	)		(47	)
	Net settlements on derivative contracts:
	Crude oil		7,344			5,755
	Natural gas		673			32
	Net premiums incurred on derivative contracts:
	Crude oil		—			5,609
	Ending fair value of commodity derivatives	$	(36,397	)	$	(3,397	)
	Balance Sheet Presentation
	The Company's derivatives are presented on a net basis as "Fair value of derivative instruments" on the condensed consolidated balance sheets. The following information summarizes the gross fair values of derivative instruments, presenting the impact of offsetting the derivative assets and liabilities on the Company's condensed consolidated balance sheets (in thousands):
		June 30, 2014
		Gross Amount			Gross Amounts			Net Amounts
		of Recognized			Offset in the			Presented in
		Assets			Condensed			the Condensed
					Consolidated			Consolidated
		Balance Sheets			Balance Sheets
Offsetting Derivative Assets:
Current asset	$	1,202		$	(1,138	)	$	64
Long-term asset		2,025			(1,917	)		108
Total asset	$	3,227		$	(3,055	)	$	172
Offsetting Derivative Liabilities:
Current liability	$	(28,286	)	$	1,138		$	(27,148	)
Long-term liability		(11,338	)		1,917			(9,421	)
Total liability	$	(39,624	)	$	3,055		$	(36,569	)
	December 31, 2013
	Gross Amount			Gross Amounts			Net Amounts
	of Recognized			Offset in the			Presented in
	Assets			Condensed			the Condensed
				Consolidated			Consolidated
				Balance Sheets			Balance Sheets
Offsetting Derivative Assets:
Current asset	$	4,049		$	(4,049	)	$	—
Long-term asset		3,310			(2,006	)		1,304
Total asset	$	7,359		$	(6,055	)	$	1,304
Offsetting Derivative Liabilities:
Current liability	$	(8,672	)	$	4,049		$	(4,623	)
Long-term liability		(2,084	)		2,006			(78	)
Total liability	$	(10,756	)	$	6,055		$	(4,701	)

Fair_Value_of_Financial_Instru

Fair Value of Financial Instruments	6 Months Ended
	Jun. 30, 2014
Fair Value of Financial Instruments	'
Fair Value of Financial Instruments	'
	Note 8. Fair Value of Financial Instruments
	Measurements of fair value of derivative instruments are classified according to the fair value hierarchy, which prioritizes the inputs to the valuation techniques used to measure fair value. Fair value is the price that would be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are classified and disclosed in one of the following categories:
	Level 1: Measured based on unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. Active markets are considered 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: Measured based on quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability. This category includes those derivative instruments that can be valued using observable market data. Substantially all of these inputs are observable in the marketplace throughout the term of the derivative instrument, can be derived from observable data, or supported by observable levels at which transactions are executed in the marketplace.
	Level 3: Measured based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable from objective sources (i.e. supported by little or no market activity). The valuation models used to value derivatives associated with the Company's oil and natural gas production are primarily industry standard models that consider various inputs including: (a) quoted forward prices for commodities, (b) time value and (c) current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Although third party quotes are utilized to assess the reasonableness of the prices and valuation techniques, there is not sufficient corroborating evidence to support classifying these assets and liabilities as Level 2.
	Financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. Management's assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels.
	Fair Value on a Recurring Basis
	The following tables set forth, by level within the fair value hierarchy, the Company's financial assets and liabilities that were accounted for at fair value on a recurring basis as of June 30, 2014 and December 31, 2013 (in thousands):
		As of June 30, 2014
		Active Market			Observable			Unobservable			Total
		for Identical			Inputs			Inputs			Carrying
		Assets			(Level 2)			(Level 3)			Value
		(Level 1)
	Cash and cash equivalents:
	Money market funds	$	250,001		$	—		$	—		$	250,001
	Oil derivative instruments:
	Swaps		—			(19,434	)		—			(19,434	)
	Enhanced Swaps		—			—			(7,785	)		(7,785	)
	Three-way collars		—			—			(8,203	)		(8,203	)
	Collars		—			—			(954	)		(954	)
	Puts		—			—			14			14
	Gas derivative instruments:
	Swaps		—			(189	)		—			(189	)
	Enhanced Swaps		—			—			205			205
	Collars		—			—			(51	)		(51	)
	Total	$	250,001		$	(19,623	)	$	(16,774	)	$	213,604
		As of December 31, 2013
		Active Market			Observable			Unobservable			Total
		for Identical			Inputs			Inputs			Carrying
		Assets			(Level 2)			(Level 3)			Value
		(Level 1)
	Cash and cash equivalents:
	Money market funds	$	105,205		$	—		$	—		$	105,205
	Oil derivative instruments:
	Swaps		—			(2,841	)		—			(2,841	)
	Three-way collars		—			—			(398	)		(398	)
	Collars		—			—			3			3
	Puts		—			—			(146	)		(146	)
	Gas derivative instruments:
	Swaps		—			(37	)		—			(37	)
	Collars		—			—			22			22
	Total	$	105,205		$	(2,878	)	$	(519	)	$	101,808
	Financing arrangements:    The Company filed a registration statement for its 7.75% Notes in an exchange offer filed with the SEC, which became effective on June 20, 2014, creating an active market for the 7.75% Notes, and as such, results in a Level 1 fair value measurement. The estimated fair value of the 7.75% Notes was $660 million as of June 30, 2014, and was calculated using quoted market prices based on trades of such debt as of that date. The Company uses a market approach to determine fair value of its unregistered 6.125% Notes using observable market data, which results in a Level 2 fair value measurement. The estimated fair value of the 6.125% Notes was $875.5 million as of June 30, 2014, and was calculated using quoted market prices based on trades of such debt as of that date.
	Financial Instruments:    The Level 1 instruments presented in the table above consist of money market funds included in cash and cash equivalents on the Company's condensed consolidated balance sheet as of June 30, 2014 and December 31, 2013. The Company's money market funds represent cash equivalents backed by the assets of high-quality banks and financial institutions. The Company identified the money market funds as Level 1 instruments due to the fact that the money market funds have daily liquidity, quoted prices for the underlying investments can be obtained and there are active markets for the underlying investments.
	The Level 2 instruments presented in the table above consist of commodity derivatives. These asset values can be closely approximated using simple models and extrapolation methods using known, observable prices as parameters.
	The Company's derivative instruments, which consist of swaps, enhanced swaps, collars and puts, are classified as either Level 2 or Level 3 in the table above. The fair values of the Company's derivatives are based on third party pricing models which utilize inputs that are either readily available in the public market, such as forward curves, or can be corroborated from active markets of broker quotes. These values are then compared to the values given by the Company's counterparties for reasonableness. Since swaps do not include optionality and therefore generally have no unobservable inputs, they are classified as Level 2. The Company's enhanced swaps, puts, collars and three-way collars include some level of unobservable input, such as volatility curves, and are therefore classified as Level 3. Derivative instruments are also subject to the risk that counterparties will be unable to meet their obligations. Such non- performance risk is considered in the valuation of the Company's derivative instruments, but to date has not had a material impact on estimates of fair values. Significant changes in the quoted forward prices for commodities and changes in market volatility generally lead to corresponding changes in the fair value measurement of the Company's derivative instruments.
	The fair values of the Company's derivative instruments classified as Level 3 as of June 30, 2014 and December 31, 2013 were ($16.8) million and ($0.5) million, respectively. The significant unobservable inputs for Level 3 contracts include unpublished forward prices of commodities, market volatility and credit risk of counterparties. Changes in these inputs will impact the fair value measurement of the Company's derivative contracts.
	The following table sets forth a reconciliation of changes in the fair value of the Company's derivative instruments classified as Level 3 in the fair value hierarchy (in thousands):
		Significant Unobservable Inputs (Level 3)
		Three Months						Six Months
		Ended June 30,						Ended June 30,
		2014			2013			2014			2013
	Beginning balance	$	(2,516	)	$	932		$	(519	)	$	3,015
	Total gains (losses) included in earnings		(15,391	)		2,165			(17,800	)		151
	Net settlements on derivative contracts		1,133			(94	)		1,545			(163	)
	Ending balance	$	(16,774	)	$	3,003		$	(16,774	)	$	3,003
	Gains (losses) included in earnings related to derivatives still held as of June 30, 2014 and 2013	$	(14,259	)	$	2,526		$	(16,255	)	$	893
	Fair Value on a Non-Recurring Basis
	The Company follows the provisions of ASC 820-10 for nonfinancial assets and liabilities measured at fair value on a non-recurring basis. Fair-value measurements of assets acquired and liabilities assumed in business combinations are based on inputs that are not observable in the market and thus represent Level 3 inputs. The fair value of acquired properties is based on market and cost approaches. Our purchase price allocations for the Catarina, Cotulla and Wycross acquisitions are presented in Note 3. Liabilities assumed include asset retirement obligations existing at the date of acquisition. The asset retirement obligation estimates are derived from historical costs as well as management's expectation of future cost environments. As there is no corroborating market activity to support the assumptions, the Company has designated these liabilities as Level 3. A reconciliation of the beginning and ending balances of the Company's asset retirement obligations is presented in Note 9.
	In connection with the exchange agreements entered into in February and May 2014 by the Company with certain holders of the Company's Series A Preferred Stock and Series B Preferred Stock, the Company issued common stock according to the conversion rate pursuant to each agreement and additional shares to induce the holders of the preferred stock to convert prior to the date the Company could mandate conversion. The fair value of the common stock issued is based on the price of the Company's common stock on the date of issuance. As there is an active market for the Company's common stock, the Company has designated this fair value measurement as Level 1. A detailed description of the Company's common stock and preferred stock issuances and redemptions is presented in Note 12.

Asset_Retirement_Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligations	'
Asset Retirement Obligations	'
	Note 9. Asset Retirement Obligations
	Asset retirement obligations represent the present value of the estimated cash flows expected to be incurred to plug, abandon and remediate producing properties, excluding salvage values, at the end of their productive lives in accordance with applicable laws. The significant unobservable inputs to this fair value measurement include estimates of plugging, abandonment and remediation costs, well life, inflation and credit-adjusted risk-free rate. The inputs are calculated based on historical data as well as current estimates. When the liability is initially recorded, the carrying amount of the related long-lived asset is increased. Over time, accretion of the liability is recognized each period, and the capitalized cost is amortized over the useful life of the related asset. Upon settlement of the liability, any gain or loss is treated as an adjustment to the full cost pool.
	The changes in the asset retirement obligation for the six months ended June 30, 2014 and the year ended December 31, 2013 were as follows (in thousands):
		2014		2013
	Abandonment liability, beginning of period	$	4,130	$	546
	Liabilities incurred during period		1,450		1,122
	Acquisitions		14,723		1,296
	Revisions		2,056		968
	Accretion expense		267		198
	Abandonment liability, end of period	$	22,626	$	4,130
	During the first quarter of 2014, the Company reviewed its asset retirement obligation estimates. A quote was obtained from a third party that indicated anticipated costs for future abandonment had increased from previous estimates. As a result, the Company increased its estimates of future asset retirement obligations by $2.1 million to reflect anticipated increased costs for plugging and abandonment. During the first quarter of 2013, the Company performed a similar exercise to update its asset retirement obligation estimates. As a result, the Company increased its estimates of future asset retirement obligations by $1.0 million to reflect anticipated increased costs for plugging and abandonment.

Related_Party_Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2014
Related Party Transactions	'
Related Party Transactions	'
	Note 10. Related Party Transactions
	Sanchez Oil & Gas Corporation ("SOG"), headquartered in Houston, Texas, is a private full service oil and natural gas company engaged in the exploration and development of oil and natural gas primarily in the South Texas and onshore Gulf Coast areas on behalf of its affiliates. The Company refers to SOG, Sanchez Energy Partners I, LP ("SEP I"), and their affiliates (but excluding the Company) collectively as the "Sanchez Group."
	The Company does not have any employees. On December 19, 2011 it entered into a services agreement with SOG pursuant to which specified employees of SOG provide certain services with respect to the Company's business under the direction, supervision and control of SOG. Pursuant to this arrangement, SOG performs centralized corporate functions for the Company, such as general and administrative services, geological, geophysical and reserve engineering, lease and land administration, marketing, accounting, operational services, information technology services, compliance, insurance maintenance and management of outside professionals. The Company compensates SOG for the services at a price equal to SOG's cost of providing such services, including all direct costs and indirect administrative and overhead costs (including the allocable portion of salary, bonus, incentive compensation and other amounts paid to persons that provide the services on SOG's behalf) allocated in accordance with SOG's regular and consistent accounting practices, including for any such costs arising from amounts paid directly by other members of the Sanchez Group on SOG's behalf or borrowed by SOG from other members of the Sanchez Group, in each case, in connection with the performance by SOG of services on the Company's behalf. The Company also reimburses SOG for sales, use or other taxes, or other fees or assessments imposed by law in connection with the provision of services to the Company (other than income, franchise or margin taxes measured by SOG's net income or margin and other than any gross receipts or other privilege taxes imposed on SOG) and for any costs and expenses arising from or related to the engagement or retention of third party service providers.
	Salaries and associated benefit costs of SOG employees are allocated to the Company based on the actual time spent by the professional staff on the properties and business activities of the Company. General and administrative costs, such as office rent, utilities, supplies, and other overhead costs, are allocated to the Company based on a fixed percentage that is reviewed quarterly and adjusted, if needed, based on the activity levels of services provided to the Company. General and administrative costs that are specifically incurred by or for the specific benefit of the Company are charged directly to the Company. Expenses allocated to the Company for general and administrative expenses for the three and six months ended June 30, 2014 and 2013 are as follows (in thousands):
		Three Months				Six Months Ended
		Ended June 30,				June 30,
		2014		2013		2014		2013
	Administrative fees	$	6,330	$	3,479	$	12,462	$	5,902
	Third party expenses		1,776		104		2,683		2,284
	Total included in general and administrative expenses	$	8,106	$	3,583	$	15,145	$	8,186
	As of June 30, 2014 and December 31, 2013, the Company had a net payable to SOG and other members of the Sanchez Group of $1.9 million and $1.0 million, respectively, which are reflected as "Accounts payable—related entities" in the condensed consolidated balance sheets. The net payables consist primarily of obligations for general and administrative costs due to SOG and revenue payable to affiliated entities.
	TMS Asset Purchase
	In August 2013, we acquired approximately 40,000 net undeveloped acres in what we believe to be the core of the TMS for cash and shares of our common stock plus an initial 3 gross (1.5 net) well drilling carry. In connection with the TMS transactions, we established an Area of Mutual Interest ("AMI") in the TMS with SR Acquisition I, LLC ("SR"), a subsidiary of our affiliate Sanchez Resources, LLC ("Sanchez Resources"). Sanchez Resources is indirectly owned, in part, by our President and Chief Executive Officer and the Executive Chairman of the Company's Board of Directors (the "Board"), who each also serve on our Board. Additionally, Eduardo Sanchez, Patricio Sanchez and Ana Lee Sanchez Jacobs, each an immediate family member of our President and Chief Executive Officer and the Executive Chairman of our Board, collectively, either directly or indirectly, own a majority of the equity interests of Sanchez Resources. Sanchez Resources is managed by Eduardo Sanchez, who is the brother of our President and Chief Executive Officer and the son of our Executive Chairman of the Board.
	As part of the transaction, we acquired all of the working interests in the AMI owned at closing from three sellers (two third parties and one related party of the Company, SR) resulting in our owning an undivided 50% working interest across the AMI through the TMS. The AMI holds rights to approximately 115,000 gross acres and 80,000 net acres.
	Total consideration for the TMS transactions consisted of approximately $70 million in cash and the issuance of 342,760 common shares of the Company, valued at $7.5 million. The cash consideration provided to SR was $14.4 million. The acquisitions were accounted for as the purchase of assets at cost on the acquisition date.
	We have also committed, as a part of the total consideration, to carry SR for its 50% working interest in an initial 3 gross (1.5 net) TMS wells to be drilled within the AMI. In the event that we do not fulfill our obligations in a timely manner with regard to the initial TMS well commitment, we must re-assign the working interests acquired from SR. At the point that the minimum commitment is met, we will have fully paid for and earned all of our rights to the TMS acreage. If we desire, at our sole discretion, to continue drilling within the AMI after fulfilling the minimum well commitment, we would be required to carry SR in an additional 3 gross (1.5 net) TMS wells.

Accrued_Liabilities

Accrued Liabilities	6 Months Ended
	Jun. 30, 2014
Accrued Liabilities	'
Accrued Liabilities	'
	Note 11. Accrued Liabilities
	The following information summarizes accrued liabilities as of June 30, 2014 and December 31, 2013 (in thousands):
		June 30,		December 31,
		2014		2013
	Capital expenditures	$	98,989	$	86,883
	General and administrative costs		7,017		550
	Production taxes		3,017		2,903
	Ad valorem taxes		4,385		981
	Lease operating expenses		7,772		8,977
	Interest payable		2,372		2,161
	Total accrued liabilities	$	123,552	$	102,455

Stockholders_Equity

Stockholders' Equity	6 Months Ended
	Jun. 30, 2014
Stockholders' Equity	'
Stockholders' Equity	'
	Note 12. Stockholders' Equity
	Common Stock Offerings—On September 18, 2013, the Company completed a public offering of 11,040,000 shares of common stock (including 1,440,000 shares purchased pursuant to the full exercise of the underwriters' overallotment option), at an issue price of $23.00 per share. The Company received net proceeds from this offering of $241.4 million, after deducting underwriters' fees and offering expenses of $12.5 million. The Company used the net proceeds from the offering to partially fund the Wycross acquisition completed in October 2013 and a portion of the 2013 capital budget, and intends to use the remaining proceeds to fund a portion of the 2014 capital budget and for general corporate purposes.
	On June 12, 2014, the Company completed a public offering of 5,000,000 shares of common stock, at an issue price of $35.25 per share. The Company received net proceeds from this offering of $167.6 million, after deducting underwriters' fees and offering expenses of $8.7 million. The Company intends to use the net proceeds from the offering to partially fund the 2014 capital budget and for general corporate purposes.
	Series A Convertible Perpetual Preferred Stock Offering—On September 17, 2012, the Company completed a private placement of 3,000,000 shares of Series A Convertible Perpetual Preferred Stock, which were sold to a group of qualified institutional buyers pursuant to the Rule 144A exemption from registration under the Securities Act of 1933, as amended. The issue price of each share of the Series A Convertible Perpetual Preferred Stock was $50.00. The Company received net proceeds from the private placement of $144.5 million, after deducting initial purchasers' discounts and commissions and offering costs payable by the Company of $5.5 million. Pursuant to the Certificate of Designations for the Series A Convertible Perpetual Preferred Stock, each share of Series A Convertible Perpetual Preferred Stock is convertible at any time at the option of the holder thereof at an initial conversion rate of 2.3250 shares of common stock per share of Series A Convertible Perpetual Preferred Stock (which is equal to an initial conversion price of $21.51 per share of common stock) and is subject to specified adjustments. Based on the initial conversion price, 4,772,086 shares of common stock would be issuable upon conversion of all of the outstanding shares of the Series A Convertible Perpetual Preferred Stock.
	The annual dividend on each share of Series A Convertible Perpetual Preferred Stock is 4.875% on the liquidation preference of $50.00 per share and is payable quarterly, in arrears, on each January 1, April 1, July 1 and October 1, when, as and if declared by the Board. No dividends were accrued or accumulated prior to September 17, 2012. The Company may, at its option, pay dividends in cash and, subject to certain conditions, common stock or any combination thereof. As of June 30, 2014, all dividends accumulated through that date had been paid.
	Except as required by law or the Company's Amended and Restated Certificate of Incorporation, holders of the Series A Convertible Perpetual Preferred Stock will have no voting rights unless dividends fall into arrears for six or more quarterly periods (whether or not consecutive). In that event and until such arrearage is paid in full, the holders of the Series A Convertible Perpetual Preferred Stock and the holders of the Series B Convertible Perpetual Preferred Stock, voting as a single class, will be entitled to elect two directors and the number of directors on the Board will increase by that same number.
	At any time on or after October 5, 2017, the Company may at its option cause all outstanding shares of the Series A Convertible Perpetual Preferred Stock to be automatically converted into common stock at the conversion price, if, among other conditions, the closing sale price (as defined) of the Company's common stock equals or exceeds 130% of the conversion price for a specified period prior to the conversion.
	If a holder elects to convert shares of Series A Convertible Perpetual Preferred Stock upon the occurrence of certain specified fundamental changes, the Company will be obligated to deliver an additional number of shares above the applicable conversion rate to compensate the holder for lost option time value of the shares of Series A Convertible Perpetual Preferred Stock as a result of the fundamental change.
	Series B Convertible Perpetual Preferred Stock Offering—On March 26, 2013, the Company completed a private placement of 4,500,000 shares of Series B Convertible Perpetual Preferred Stock. The issue price of each share of the Series B Convertible Perpetual Preferred Stock was $50.00. The Company received net proceeds from the private placement of $216.6 million, after deducting placement agent's fees and offering costs of $8.4 million.
	Each share of Series B Convertible Perpetual Preferred Stock is convertible at any time at the option of the holder thereof at an initial conversion rate of 2.3370 shares of common stock per share of Series B Convertible Perpetual Preferred Stock (which is equal to an initial conversion price of $21.40 per share of common stock) and is subject to specified adjustments. Based on the initial conversion price, 8,747,742 shares of common stock would be issuable upon conversion of all of the outstanding shares of the Series B Convertible Perpetual Preferred Stock.
	The annual dividend on each share of Series B Convertible Perpetual Preferred Stock is 6.500% on the liquidation preference of $50.00 per share and is payable quarterly, in arrears, on each January 1, April 1, July 1 and October 1, when, as and if declared by the Board. The Company may, at its option, pay dividends in cash and, subject to certain conditions, common stock or any combination thereof. As of June 30, 2014, all dividends accumulated through that date had been paid.
	Except as required by law or the Company's Amended and Restated Certificate of Incorporation, holders of the Series B Convertible Perpetual Preferred Stock will have no voting rights unless dividends fall into arrears for six or more quarterly periods (whether or not consecutive). In that event and until such arrearage is paid in full, the holders of the Series B Convertible Perpetual Preferred Stock and the holders of the Series A Convertible Perpetual Preferred Stock, voting as a single class, will be entitled to elect two directors and the number of directors on the Board will increase by that same number.
	At any time on or after April 6, 2018, the Company may at its option cause all outstanding shares of the Series B Convertible Preferred Stock to be automatically converted into common stock at the conversion price, if, among other conditions, the closing sale price (as defined) of the Company's common stock equals or exceeds 130% of the conversion price for a specified period prior to the conversion.
	If a holder elects to convert shares of Series B Convertible Perpetual Preferred Stock upon the occurrence of certain specified fundamental changes, the Company will be obligated to deliver an additional number of shares above the applicable conversion rate to compensate the holder for lost option time value of the shares of Series B Convertible Perpetual Preferred Stock as a result of the fundamental change.
	Preferred Stock Exchange—On February 12, 2014 and February 13, 2014, the Company entered into exchange agreements with certain holders (the "February 2014 Holders") of the Company's Series A Convertible Perpetual Preferred Stock, and of Series B Convertible Perpetual Preferred Stock, pursuant to which such holders agreed to exchange an aggregate of (i) 947,490 shares of Series A Convertible Perpetual Preferred Stock (and waive their rights to any accrued and unpaid dividends thereon) for 2,425,574 shares of the Company's common stock, and (ii) 756,850 shares of the Series B Convertible Perpetual Preferred Stock (and waive their rights to any accrued and unpaid dividends thereon) for 2,021,066 shares of common stock.
	Additionally, on May 29, 2014, the Company entered into exchange agreements with certain holders (the "May 2014 Holders", and together with the February 2014 Holders, the "Holders") of the Company's Series A Convertible Perpetual Preferred Stock, and of Series B Convertible Perpetual Preferred Stock, pursuant to which such holders agreed to exchange an aggregate of (i) 166,025 shares of Series A Convertible Perpetual Preferred Stock (and waive their rights to any accrued and unpaid dividends thereon) for 418,715 shares of the Company's common stock, and (ii) 210,820 shares of the Series B Convertible Perpetual Preferred Stock (and waive their rights to any accrued and unpaid dividends thereon) for 553,980 shares of common stock.
	Since the Holders were not entitled to any consideration over and above the initial conversion rates of 2.325 and 2.337 common shares for each preferred share exchanged for Series A Convertible Perpetual Preferred Stock and Series B Convertible Perpetual Preferred Stock, respectively, any consideration is considered an inducement for the Holders to convert earlier than the Company could have forced conversion.
	The Company has determined the fair value of consideration transferred to the Holders and the fair value of consideration transferrable pursuant to the original conversion terms. The $13.9 million and $3.1 million excess of the fair value of the shares of common stock issued over the carrying value of the Series A Preferred Stock and Series B Preferred Stock redeemed for the February and May conversions, respectively, has been reflected as an additional preferred stock dividend, that is, as a reduction of retained earnings to arrive at net income attributable to common shareholders in our condensed consolidated financial statements.
	Earnings (Loss) Per Share—The following table shows the computation of basic and diluted net income (loss) per share for the three and six months ended June 30, 2014 and 2013 (in thousands, except per share amounts):
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
	Net income (loss)	$	(12,158	)	$	8,890		$	(8,713	)	$	8,816
	Less:
	Preferred stock dividends		(7,132	)		(5,484	)		(25,325	)		(7,556	)
	Net income allocable to participating securities(1)		—			(159	)		—			(56	)
	Net income (loss) attributable to common stockholders	$	(19,290	)	$	3,247		$	(34,038	)	$	1,204
	Weighted average number of unrestricted outstanding common shares used to calculate basic net income (loss) per share		50,602			33,117			48,825			33,108
	Dilutive shares(2)(3)		—			—			—			—
	Denominator for diluted net income (loss) per common share		50,602			33,117			48,825			33,108
	Net income (loss) per common share—basic and diluted	$	(0.38	)	$	0.1		$	(0.70	)	$	0.04
	-1
	For the three and six months ended June 30, 2014, no losses were allocated to participating restricted stock because such securities do not have a contractual obligation to share in the Company's losses.
	-2
	The three and six months ended June 30, 2014 excludes 423,771 and 829,375 shares of weighted average restricted stock and 13,253,510 and 14,502,257 shares of common stock resulting from an assumed conversion of the Company's Series A Convertible Perpetual Preferred Stock and Series B Convertible Perpetual Preferred Stock from the calculation of the denominator for diluted earnings per common share as these shares were anti-dilutive.
	-3
	The three and six months ended June 30, 2013 excludes 208,130 and 539,141 shares of weighted average restricted stock and 17,491,500 and 12,466,950 shares of common stock resulting from an assumed conversion of the Company's Series A Convertible Perpetual Preferred Stock and Series B Convertible Perpetual Preferred Stock from the calculation of the denominator for diluted earnings per common share as these shares were anti-dilutive.

StockBased_Compensation

Stock-Based Compensation	6 Months Ended
	Jun. 30, 2014
Stock-Based Compensation	'
Stock-Based Compensation	'
	Note 13. Stock-Based Compensation
	At the Annual Meeting of Stockholders of the Company held on May 23, 2012, the Company's stockholders approved the Sanchez Energy Corporation Amended and Restated 2011 Long Term Incentive Plan (the "LTIP"). The Board had previously approved the amendment of the LTIP on April 16, 2012, subject to stockholder approval.
	The Company's directors and consultants as well as employees of the Sanchez Group who provide services to the Company are eligible to participate in the LTIP. Awards to participants may be made in the form of restricted shares, phantom shares, share options, share appreciation rights and other share-based awards. The maximum number of shares that may be delivered pursuant to the LTIP is limited to 15% of the Company's issued and outstanding shares of common stock. This maximum amount automatically increases to 15% of the issued and outstanding shares of common stock immediately after each issuance by the Company of its common stock, unless the Board determines to increase the maximum number of shares of common stock by a lesser amount. Shares withheld to satisfy tax withholding obligations are not considered to be delivered under the LTIP. In addition, if an award is forfeited, canceled, exercised, paid or otherwise terminates or expires without the delivery of shares, the shares subject to such award are then available for new awards under the LTIP. Shares delivered pursuant to awards under the LTIP may be newly issued shares, shares acquired by the Company in the open market, shares acquired by the Company from any other person, or any combination of the foregoing.
	The LTIP is administered by the Board. The Board may terminate or amend the LTIP at any time with respect to any shares for which a grant has not yet been made. The Board has the right to alter or amend the LTIP or any part of the LTIP from time to time, including increasing the number of shares that may be granted, subject to shareholder approval as may be required by the exchange upon which the common shares are listed at that time, if any. No change may be made in any outstanding grant that would materially reduce the benefits of the participant without the consent of the participant. The LTIP will expire upon its termination by the Board or, if earlier, when no shares remain available under the LTIP for awards. Upon termination of the LTIP, awards then outstanding will continue pursuant to the terms of their grants.
	The Company records stock-based compensation expense for awards granted to its directors (for their services as directors) in accordance with the provisions of ASC 718, "Compensation—Stock Compensation." Stock- based compensation expense for these awards is based on the grant-date fair value and recognized over the vesting period using the straight-line method.
	Awards granted to employees of the Sanchez Group (including those employees of the Sanchez Group who also serve as the Company's officers) and consultants in exchange for services are considered awards to non-employees and the Company records stock-based compensation expense for these awards at fair value in accordance with the provisions of ASC 505-50, "Equity-Based Payments to Non-Employees." For awards granted to non-employees, the Company records compensation expenses equal to the fair value of the stock-based award at the measurement date, which is determined to be the earlier of the performance commitment date or the service completion date. Compensation expense for unvested awards to non-employees is revalued at each period end and is amortized over the vesting period of the stock-based award. Stock-based payments are measured based on the fair value of the equity instruments granted, as it is more determinable than the value of the services rendered.
	For the restricted stock awards granted to non-employees, stock-based compensation expense is based on fair value remeasured at each reporting period and recognized over the vesting period using the straight-line method. Compensation expense for these awards will be revalued at each period end until vested.
	The Company recognized the following stock-based compensation expense for the periods indicated which is reflected as general and administrative expense in the condensed consolidated statements of operations (in thousands):
		Three Months Ended					Six Months Ended
		June 30,					June 30,
		2014			2013		2014		2013
	Restricted stock awards, directors	$	262		$	138	$	560	$	231
	Restricted stock awards, non-employees		15,681			4,440		25,318		7,481
	Total stock-based compensation expense	$	15,943		$	4,578	$	25,878	$	7,712
	Based on the $37.59 per share closing price of the Company's common stock on June 30, 2014, there was $68.0 million of unrecognized compensation cost related to these non-vested restricted shares outstanding. The cost is expected to be recognized over an average period of approximately 1.9 years.
	A summary of the status of the non-vested shares as of June 30, 2014 is presented below (in thousands):
		Number of
		Non-Vested
		Shares
	Non-vested common stock as of December 31, 2013		1,758
	Granted		1,646
	Vested		(636	)
	Forfeited		(309	)
	Non-vested common stock as of June 30, 2014		2,459
	As of June 30, 2014, approximately 4.9 million shares remain available for future issuance to participants.

Income_Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2014
Income Taxes	'
Income Taxes	'
	Note 14. Income Taxes
	The Company's estimated annual effective income tax rates are used to allocate expected annual income tax expense to interim periods. The rates are determined based on the ratio of estimated annual income tax expense to estimated annual income before income taxes by taxing jurisdiction, except for discrete items, which are significant, unusual or infrequent items for which income taxes are computed and recorded in the interim period in which the specific transaction occurs. The estimated annual effective income tax rates are applied to the year-to-date income before income taxes by taxing jurisdiction to determine the income tax expense allocated to the interim period. The Company updates its estimated annual effective income tax rate at the end of each quarterly period considering the geographic mix of income based on the tax jurisdictions in which the Company operates. Actual results that are different from the assumptions used in estimating the annual effective income tax rate will impact future income tax expense. The difference between the statutory federal income taxes calculated using a U.S. Federal statutory corporate income tax rate of 35% and the Company's effective tax rate of 34.9% for the six months ended June 30, 2014 is related to non-deductible general and administrative expenses recorded during the period. Our effective tax rate for the three months ended June 30, 2014 was equal to the statutory rate of 35%. The Company's effective tax rate for the three and six months ended June 30, 2013 was 0%, due to the change in valuation allowance recorded against net deferred income tax assets.
	As of June 30, 2014, the Company had estimated net operating loss carryforwards of $660.5 million, which will begin to expire in 2031.
	In recording deferred income tax assets, the Company considers whether it is more likely than not that some portion or all of the deferred income tax assets will be realized. The ultimate realization of deferred income tax assets is dependent upon the generation of future taxable income during the periods in which those deferred income tax assets would be deductible. The Company believes that after considering all the available objective evidence, both positive and negative, historical and prospective, with greater weight given to historical evidence, it is more likely than not that the deferred tax assets will be realized and therefore reversed the valuation allowance against its net deferred tax asset in the third quarter of 2013. There was no change in the valuation allowance during the three and six months ended June 30, 2014. The Company will continue to assess the valuation allowance against deferred tax assets considering all available information obtained in future reporting periods.
	As of June 30, 2014, the Company had no material uncertain tax positions.

Commitments_and_Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies	'
Commitments and Contingencies	'
	Note 15. Commitments and Contingencies
	From time to time, the Company may be involved in lawsuits that arise in the normal course of its business. On December 4, 13 and 16, 2013, three derivative actions were filed in the Court of Chancery of the State of Delaware against the Company, certain of its officers and directors, Sanchez Resources, Altpoint Capital Partners LLC and Altpoint Sanchez Holdings, LLC (the "Consolidated Derivative Actions," Friedman v. A.R. Sanchez, Jr. et al., No. 9158; City of Roseville Employees' Retirement System v. A.R. Sanchez, Jr. et al., No. 9132; and Delaware County Employees Retirement Fund v. A.R. Sanchez, Jr. et al., No. 9165).
	On December 20, 2013, the Consolidated Derivative Actions were consolidated, co-lead counsel for the plaintiffs was appointed and the plaintiffs were ordered to file an amended consolidated complaint (In re Sanchez Energy Derivative Litigation, Consolidated C.A. No. 9132-VCG, hereinafter, the "Delaware Derivative Action"). On January 28, 2014, a verified consolidated stockholder derivative complaint was filed. The Consolidated Derivative Actions concern the Company's purchase of working interests in the TMS from Sanchez Resources. Plaintiffs allege breaches of fiduciary duty against the individual defendants as directors of the Company; breaches of fiduciary duty against Antonio R. Sanchez, III as an executive director of the Company; aiding and abetting breaches of fiduciary duty against Sanchez Resources, Eduardo Sanchez, Altpoint Capital Partners LLC and Altpoint Sanchez Holdings, LLC; and unjust enrichment against A.R. Sanchez, Jr. and Antonio R. Sanchez, III. All of the defendants filed a motion to dismiss on April 1, 2014. Briefing concerning the motions to dismiss concluded on June 27, 2014, but no ruling has been made at this time. The Consolidated Derivative Actions are in their preliminary stages, and the Company is unable to reasonably predict an outcome or to reasonably estimate a range of possible loss.
	On January 9, 2014, a derivative action was filed in 333rd district court in Harris County, Texas against the Company and certain of its officers and directors, styled Martin v. Sanchez, No. 2014-01028 (333rd Dist. Harris County, Texas) (the "Texas State Derivative Action"). The complaint alleges a breach of fiduciary duty, corporate waste and unjust enrichment against various officers and directors. No action has been taken to date and damages are unspecified. On March 14, 2014, this action was stayed following a ruling on the motion to dismiss in the Delaware Derivative Action. This action is in its preliminary stages and currently subject to the stay, and the Company is unable to reasonably predict an outcome or to estimate a range of reasonably possible loss.
	On February 12, 2014, a derivative action was filed in the United States District Court for the Southern District of Texas, Houston Division, against the Company and certain of its officers and directors, styled Bartlinski v. Sanchez, No. 4:14-cv-00341 (S.D. Tex.) (the "Texas Federal Derivative Action"). The complaint alleges a violation of Section 14(a) of the Exchange Act and SEC Rule 14a-9. No action has been taken to date and damages are unspecified. Defendants filed a motion to dismiss on April 10, 2014. Briefing concerning the motion to dismiss concluded on May 6, 2014, but no ruling has been made at this time. This action is in its preliminary stages, and the Company is unable to reasonably predict an outcome or to reasonably estimate a range of possible loss.
	Defendants believe that the allegations contained in the matters described above are without merit and intend to vigorously defend themselves against the claims raised.
	In addition, in connection with the TMS transactions, the Company has committed to carry SR for its 50% working interest in an initial 3 gross (1.5 net) TMS wells to be drilled within the AMI. In the event that we do not fulfill in a timely manner our obligations with regard to the initial TMS well commitment we must re-assign the working interests acquired from SR. At the point that the minimum commitment is met, we will have fully paid for and earned all rights to the TMS acreage. If we desire, at our sole discretion, to continue drilling within the AMI after fulfilling the minimum well commitment, we would be required to carry SR in an additional 3 gross (1.5 net) TMS wells.
	In connection with the Catarina acquisition, the 77,000 acres of undeveloped acreage that were included in the acquisition are subject to a continuous drilling obligation. Initially, such drilling obligation requires us to drill, but not complete, (i) 50 wells in each annual period commencing on July 1, 2014 and (ii) at least one well in any consecutive 120 day period in order to maintain rights to any future undeveloped acreage. Initially, up to 30 wells drilled in excess of the minimum 50 wells in a given annual period can be carried over to satisfy part of the 50 well requirement in the subsequent annual period on a well for well basis. The lease also created a customary security interest in the production therefrom in order to secure royalty payments to the lessor and other lease obligations. Our current capital budget and plans include the drilling of at least the minimum number of wells required to maintain access to such undeveloped acreage.

Subsidiary_Guarantors

Subsidiary Guarantors	6 Months Ended
	Jun. 30, 2014
Subsidiary Guarantors	'
Subsidiary Guarantors	'
	Note 16. Subsidiary Guarantors
	The Company filed a registration statement on Form S-3 with the SEC, which became effective on January 14, 2013 and registered, among other securities, debt securities. The subsidiaries of the Company named therein are co-registrants with the Company, and the registration statement registered guarantees of debt securities by such subsidiaries. As of June 30, 2014, such subsidiaries are 100 percent owned by the Company and any guarantees by these subsidiaries will be full and unconditional (except for customary release provisions). In the event that more than one of these subsidiaries provide guarantees of any debt securities issued by the Company, such guarantees will constitute joint and several obligations.
	The Company also filed a registration statement on Form S-4 with the SEC, which became effective on June 20, 2014, pursuant to which the Company completed an offering of debt securities which are guaranteed by its subsidiaries named therein. As of June 30, 2014, such guarantor subsidiaries are 100 percent owned by the Company and the guarantees by these subsidiaries are full and unconditional (except for customary release provisions) and are joint and several.
	The Company has no assets or operations independent of its subsidiaries and there are no significant restrictions upon the ability of its subsidiaries to distribute funds to the Company.

Subsequent_Events

Subsequent Events	6 Months Ended
	Jun. 30, 2014
Subsequent Events	'
Subsequent Events	'
	Note 17. Subsequent Events
	In July 2014, the Company entered into the following three-way natural gas collar contracts that combine a long and short put with a short call:
	Contract Period	Mmbtu		Short Put		Long Put		Short Call		Pricing Index
	August 1, 2014 - December 31, 2015		2,590,000	$	3.5	$	4	$	4.9	NYMEX NG
	August 1, 2014 - December 31, 2015		2,590,000	$	3.5	$	4	$	4.9	NYMEX NG
	In August 2014, the Company entered into the following three-way crude oil collar contracts that combine a long and short put with a short call:
	Contract Period	Barrels		Short Put		Long Put		Short Call		Pricing Index
	January 1, 2015 - December 31, 2015		365,000	$	75	$	90	$	97	NYMEX NG
	January 1, 2015 - December 31, 2015		365,000	$	75	$	90	$	97.25	NYMEX NG

Basis_of_Presentation_and_Summ1

Basis of Presentation and Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2014
Basis of Presentation and Summary of Significant Accounting Policies	'
Use of Estimates	'
	Use of Estimates
	The condensed consolidated financial statements are prepared in conformity with U.S. GAAP, which requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The most significant estimates pertain to proved oil and natural gas reserves and related cash flow estimates used in the calculation of depletion and impairment of oil and natural gas properties, fair value accounting for acquisitions, the evaluation of unproved properties for impairment, the fair value of commodity derivative contracts and asset retirement obligations, accrued oil and natural gas revenues and expenses and the allocation of general and administrative expenses. Actual results could differ materially from those estimates.
Recent Accounting Pronouncements	'
	Recent Accounting Pronouncements
	In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers ("ASU 2014-09"), which supersedes nearly all existing revenue recognition guidance under U.S. GAAP. The core principle of ASU 2014-09 is to recognize revenues when promised goods or services are transferred to customers in an amount that reflects the consideration to which an entity expects to be entitled for those goods or services. ASU 2014-09 defines a five step process to achieve this core principle and, in doing so, more judgment and estimates may be required within the revenue recognition process than are required under existing U.S. GAAP.
	The standard is effective for annual periods beginning after December 15, 2016, and interim periods therein, using either of the following transition methods: (i) a full retrospective approach reflecting the application of the standard in each prior reporting period with the option to elect certain practical expedients, or (ii) a retrospective approach with the cumulative effect of initially adopting ASU 2014-09 recognized at the date of adoption (which includes additional footnote disclosures). We are currently evaluating the impact of our pending adoption of ASU 2014-09 on our consolidated financial statements and have not yet determined the method by which we will adopt the standard in 2017.

Acquisitions_Tables

Acquisitions (Tables)	6 Months Ended
	Jun. 30, 2014
Catarina	'
Acquisitions	'
Schedule of total purchase price allocated to the assets purchased and liabilities assumed based upon their fair values on the date of acquisition	'
	Proved oil and natural gas properties	$	428,484
	Unproved properties		137,089
	Other assets acquired		2,682
	Fair value of assets acquired		568,255
	Asset retirement obligations		(14,723	)
	Fair value of net assets acquired	$	553,532
Cotulla	'
Acquisitions	'
Schedule of total purchase price allocated to the assets purchased and liabilities assumed based upon their fair values on the date of acquisition	'
	Proved oil and natural gas properties	$	265,466
	Unproved properties		16,745
	Fair value of assets acquired		282,211
	Asset retirement obligations		(1,138	)
	Other liabilities assumed		(190	)
	Fair value of net assets acquired	$	280,883
Wycross	'
Acquisitions	'
Schedule of total purchase price allocated to the assets purchased and liabilities assumed based upon their fair values on the date of acquisition	'
	Proved oil and natural gas properties	$	215,265
	Unproved properties		13,095
	Other assets acquired		1,523
	Fair value of assets acquired		229,883
	Asset retirement obligations		(158	)
	Other liabilities assumed		(113	)
	Fair value of net assets acquired	$	229,612
Catarina, Wycross and Cotulla	'
Acquisitions	'
Schedule of unaudited pro forma combined statements of operations	'
		Three Months Ended					Six Months Ended
		June 30,					June 30,
		2014			2013		2014			2013
	Revenues	$	216,051		$	190,468	$	445,563		$	347,865
	Net income (loss) attributable to common stockholders	$	(12,268	)	$	12,498	$	(7,920	)	$	11,028
	Net income (loss) per common share, basic	$	(0.24	)	$	0.36	$	(0.16	)	$	0.32
	Net income (loss) per common share, diluted	$	(0.24	)	$	0.34	$	(0.16	)	$	0.32
Schedule of revenue and revenues in excess of direct operating expenses	'
		Three Months Ended					Six Months Ended
		June 30,					June 30,
		2014			2013		2014			2013
	Revenues	$	54,937		$	8,474	$	109,408		$	8,474
	Excess of revenues over direct operating expenses	$	45,136		$	4,929	$	86,505		$	4,929

Cash_and_Cash_Equivalents_Tabl

Cash and Cash Equivalents (Tables)	6 Months Ended
	Jun. 30, 2014
Cash and Cash Equivalents	'
Schedule of cash and cash equivalents	'
		June 30,		December 31,
		2014		2013
	Cash at banks	$	135,870	$	48,326
	Money market funds		250,001		105,205
	Total cash and cash equivalents	$	385,871	$	153,531

LongTerm_Debt_Tables

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Long-Term Debt	'
Schedule of long-term debt	'
		Interest Rate	Maturity date	Amount
				Outstanding
				(in thousands)
	Second amended and restated credit agreement	Variable	June 30, 2019	$	—
	7.75% Notes	7.75%	June 15, 2021		600,000
	6.125% Notes	6.13%	January 15, 2023		850,000
					1,450,000
	Unamortized discount on Senior Notes				(6,290	)
	Total long-term debt			$	1,443,710

Derivative_Instruments_Tables

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative contract covering anticipated future production	'
Schedule of three-way crude oil collar contracts that combine a long and short put with a short call	'
	Contract Period	Barrels			Short Put			Long Put			Short Call			Pricing Index
	July 1, 2014 - December 31, 2014		276,000		$	65		$	85		$	102.25		NYMEX WTI
	July 1, 2014 - December 31, 2014		184,000		$	75		$	95		$	107.5		LLS
	July 1, 2014 - December 31, 2014		184,000		$	75		$	90		$	96.22		NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000		$	70		$	85		$	95		NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000		$	70		$	85		$	95		NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000		$	70		$	85		$	94.75		NYMEX WTI
Schedule of reconciliation of the changes in fair value of the Company's commodity derivatives	'
		June 30, 2014			December 31, 2013
	Beginning fair value of commodity derviatives	$	(3,397	)	$	2,145
	Net losses on crude oil derivatives		(40,323	)		(16,891	)
	Net losses on natural gas derivatives		(694	)		(47	)
	Net settlements on derivative contracts:
	Crude oil		7,344			5,755
	Natural gas		673			32
	Net premiums incurred on derivative contracts:
	Crude oil		—			5,609
	Ending fair value of commodity derivatives	$	(36,397	)	$	(3,397	)
Summary of gross fair values of derivative instruments, presenting the impact of offsetting the derivative assets and liabilities on the condensed consolidated balance sheets	'
		June 30, 2014
		Gross Amount			Gross Amounts			Net Amounts
		of Recognized			Offset in the			Presented in
		Assets			Condensed			the Condensed
					Consolidated			Consolidated
					Balance Sheets			Balance Sheets
	Offsetting Derivative Assets:
	Current asset	$	1,202		$	(1,138	)	$	64
	Long-term asset		2,025			(1,917	)		108
	Total asset	$	3,227		$	(3,055	)	$	172
	Offsetting Derivative Liabilities:
	Current liability	$	(28,286	)	$	1,138		$	(27,148	)
	Long-term liability		(11,338	)		1,917			(9,421	)
	Total liability	$	(39,624	)	$	3,055		$	(36,569	)
		December 31, 2013
		Gross Amount			Gross Amounts			Net Amounts
		of Recognized			Offset in the			Presented in
		Assets			Condensed			the Condensed
					Consolidated			Consolidated
					Balance Sheets			Balance Sheets
	Offsetting Derivative Assets:
	Current asset	$	4,049		$	(4,049	)	$	—
	Long-term asset		3,310			(2,006	)		1,304
	Total asset	$	7,359		$	(6,055	)	$	1,304
	Offsetting Derivative Liabilities:
	Current liability	$	(8,672	)	$	4,049		$	(4,623	)
	Long-term liability		(2,084	)		2,006			(78	)
	Total liability	$	(10,756	)	$	6,055		$	(4,701	)
Crude oil	'
Derivative contract covering anticipated future production	'
Schedule of derivative instruments covering the entity's anticipated future production	'
	Contract Period	Derivative		Barrels			Purchased			Sold			Pricing Index
		Instrument
	July 1, 2014 - December 31, 2014	Swap			138,000		$	92			n/a		NYMEX WTI
	July 1, 2014 - December 31, 2014	Swap			138,000		$	91.35			n/a		NYMEX WTI
	July 1, 2014 - December 31, 2014	Swap			138,000		$	92.45			n/a		NYMEX WTI
	July 1, 2014 - December 31, 2014	Swap			184,000		$	95.45			n/a		NYMEX WTI
	July 1, 2014 - December 31, 2014	Swap			184,000		$	93.25			n/a		NYMEX WTI
	January 1, 2015 - December 31, 2015	Swap			365,000		$	89.65			n/a		NYMEX WTI
	January 1, 2015 - December 31, 2015	Swap			365,000		$	90.05			n/a		NYMEX WTI
	January 1, 2015 - December 31, 2015	Swap			365,000		$	88.48			n/a		NYMEX WTI
	January 1, 2015 - December 31, 2015	Swap			365,000		$	88.35			n/a		NYMEX WTI
	July 1, 2014 - December 31, 2014	Collar			184,000		$	90		$	99.1		NYMEX WTI
	July 1, 2014 - December 31, 2014	Put Spread			184,000		$	90		$	75		NYMEX WTI
Crude oil | Enhanced Swap Purchased	'
Derivative contract covering anticipated future production	'
Schedule of derivative instruments covering the entity's anticipated future production	'
	Contract Period	Barrels			Purchased			Put			Pricing Index
	January 1, 2015 - December 31, 2015		365,000		$	91.46		$	75		NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000		$	93.13		$	75		NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000		$	92.2		$	75		NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000		$	91.46		$	75		NYMEX WTI
Natural gas	'
Derivative contract covering anticipated future production	'
Schedule of derivative instruments covering the entity's anticipated future production	'
	Contract Period	Derivative		Mmbtu			Purchased			Sold			Pricing Index
		Instrument
	July 1, 2014 - December 31, 2014	Swap			368,000		$	4.23			n/a		NYMEX NG
	July 1, 2014 - December 31, 2014	Swap			368,000		$	4.23			n/a		NYMEX NG
	July 1, 2014 - December 31, 2014	Swap			368,000		$	4.24			n/a		NYMEX NG
	July 1, 2014 - December 31, 2014	Swap			368,000		$	4.61			n/a		NYMEX NG
	July 1, 2014 - December 31, 2014	Collar			368,000		$	4		$	4.5		NYMEX NG
Natural gas | Enhanced Swap Purchased	'
Derivative contract covering anticipated future production	'
Schedule of derivative instruments covering the entity's anticipated future production	'
	Contract Period	Mmbtu			Purchased			Put			Pricing Index
	January 1, 2015 - December 31, 2015		2,190,000		$	4.44		$	3.75		NYMEX NG
	January 1, 2015 - December 31, 2015		1,095,000		$	4.4		$	3.75		NYMEX NG
	January 1, 2015 - December 31, 2015		730,000		$	4.5		$	3.75		NYMEX NG

Fair_Value_of_Financial_Instru1

Fair Value of Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value of Financial Instruments	'
Schedule of financial assets and liabilities measured at fair value on a recurring basis	'
		As of June 30, 2014
		Active Market			Observable			Unobservable			Total
		for Identical			Inputs			Inputs			Carrying
		Assets			(Level 2)			(Level 3)			Value
		(Level 1)
	Cash and cash equivalents:
	Money market funds	$	250,001		$	—		$	—		$	250,001
	Oil derivative instruments:
	Swaps		—			(19,434	)		—			(19,434	)
	Enhanced Swaps		—			—			(7,785	)		(7,785	)
	Three-way collars		—			—			(8,203	)		(8,203	)
	Collars		—			—			(954	)		(954	)
	Puts		—			—			14			14
	Gas derivative instruments:
	Swaps		—			(189	)		—			(189	)
	Enhanced Swaps		—			—			205			205
	Collars		—			—			(51	)		(51	)
	Total	$	250,001		$	(19,623	)	$	(16,774	)	$	213,604
		As of December 31, 2013
		Active Market			Observable			Unobservable			Total
		for Identical			Inputs			Inputs			Carrying
		Assets			(Level 2)			(Level 3)			Value
		(Level 1)
	Cash and cash equivalents:
	Money market funds	$	105,205		$	—		$	—		$	105,205
	Oil derivative instruments:
	Swaps		—			(2,841	)		—			(2,841	)
	Three-way collars		—			—			(398	)		(398	)
	Collars		—			—			3			3
	Puts		—			—			(146	)		(146	)
	Gas derivative instruments:
	Swaps		—			(37	)		—			(37	)
	Collars		—			—			22			22
	Total	$	105,205		$	(2,878	)	$	(519	)	$	101,808
Reconciliation of changes in the fair value of the oil derivative instruments classified as Level 3 in the fair value hierarchy	'
		Significant Unobservable Inputs (Level 3)
		Three Months						Six Months
		Ended June 30,						Ended June 30,
		2014			2013			2014			2013
	Beginning balance	$	(2,516	)	$	932		$	(519	)	$	3,015
	Total gains (losses) included in earnings		(15,391	)		2,165			(17,800	)		151
	Net settlements on derivative contracts		1,133			(94	)		1,545			(163	)
	Ending balance	$	(16,774	)	$	3,003		$	(16,774	)	$	3,003
	Gains (losses) included in earnings related to derivatives still held as of June 30, 2014 and 2013	$	(14,259	)	$	2,526		$	(16,255	)	$	893

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligations	'
Schedule of changes in asset retirement obligation	'
		2014		2013
	Abandonment liability, beginning of period	$	4,130	$	546
	Liabilities incurred during period		1,450		1,122
	Acquisitions		14,723		1,296
	Revisions		2,056		968
	Accretion expense		267		198
	Abandonment liability, end of period	$	22,626	$	4,130

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2014
Related Party Transactions	'
Schedule of expenses allocated to the Company for general and administrative expenses	'
		Three Months				Six Months Ended
		Ended June 30,				June 30,
		2014		2013		2014		2013
	Administrative fees	$	6,330	$	3,479	$	12,462	$	5,902
	Third party expenses		1,776		104		2,683		2,284
	Total included in general and administrative expenses	$	8,106	$	3,583	$	15,145	$	8,186

Accrued_Liabilities_Tables

Accrued Liabilities (Tables)	6 Months Ended
	Jun. 30, 2014
Accrued Liabilities	'
Summary of accrued liabilities	'
		June 30,		December 31,
		2014		2013
	Capital expenditures	$	98,989	$	86,883
	General and administrative costs		7,017		550
	Production taxes		3,017		2,903
	Ad valorem taxes		4,385		981
	Lease operating expenses		7,772		8,977
	Interest payable		2,372		2,161
	Total accrued liabilities	$	123,552	$	102,455

Stockholders_Equity_Tables

Stockholders' Equity (Tables)	6 Months Ended
	Jun. 30, 2014
Stockholders' Equity	'
Schedule of computation of basic and diluted net income (loss) per share	'
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
	Net income (loss)	$	(12,158	)	$	8,890		$	(8,713	)	$	8,816
	Less:
	Preferred stock dividends		(7,132	)		(5,484	)		(25,325	)		(7,556	)
	Net income allocable to participating securities(1)		—			(159	)		—			(56	)
	Net income (loss) attributable to common stockholders	$	(19,290	)	$	3,247		$	(34,038	)	$	1,204
	Weighted average number of unrestricted outstanding common shares used to calculate basic net income (loss) per share		50,602			33,117			48,825			33,108
	Dilutive shares(2)(3)		—			—			—			—
	Denominator for diluted net income (loss) per common share		50,602			33,117			48,825			33,108
	Net income (loss) per common share—basic and diluted	$	(0.38	)	$	0.1		$	(0.70	)	$	0.04
	-1
	For the three and six months ended June 30, 2014, no losses were allocated to participating restricted stock because such securities do not have a contractual obligation to share in the Company's losses.
	-2
	The three and six months ended June 30, 2014 excludes 423,771 and 829,375 shares of weighted average restricted stock and 13,253,510 and 14,502,257 shares of common stock resulting from an assumed conversion of the Company's Series A Convertible Perpetual Preferred Stock and Series B Convertible Perpetual Preferred Stock from the calculation of the denominator for diluted earnings per common share as these shares were anti-dilutive.
	-3
	The three and six months ended June 30, 2013 excludes 208,130 and 539,141 shares of weighted average restricted stock and 17,491,500 and 12,466,950 shares of common stock resulting from an assumed conversion of the Company's Series A Convertible Perpetual Preferred Stock and Series B Convertible Perpetual Preferred Stock from the calculation of the denominator for diluted earnings per common share as these shares were anti-dilutive.

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2014
Stock-Based Compensation	'
Schedule of stock-based compensation expense	'
		Three Months Ended					Six Months Ended
		June 30,					June 30,
		2014			2013		2014		2013
	Restricted stock awards, directors	$	262		$	138	$	560	$	231
	Restricted stock awards, non-employees		15,681			4,440		25,318		7,481
	Total stock-based compensation expense	$	15,943		$	4,578	$	25,878	$	7,712
Summary of the status of the non-vested shares	'
		Number of
		Non-Vested
		Shares
	Non-vested common stock as of December 31, 2013		1,758
	Granted		1,646
	Vested		(636	)
	Forfeited		(309	)
	Non-vested common stock as of June 30, 2014		2,459

Subsequent_Events_Tables

Subsequent Events (Tables)	6 Months Ended
	Jun. 30, 2014
Subsequent events	'
Schedule of three-way crude oil collar contracts that combine a long and short put with a short call	'
	Contract Period	Barrels		Short Put		Long Put		Short Call		Pricing Index
	July 1, 2014 - December 31, 2014		276,000	$	65	$	85	$	102.25	NYMEX WTI
	July 1, 2014 - December 31, 2014		184,000	$	75	$	95	$	107.5	LLS
	July 1, 2014 - December 31, 2014		184,000	$	75	$	90	$	96.22	NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000	$	70	$	85	$	95	NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000	$	70	$	85	$	95	NYMEX WTI
	January 1, 2015 - December 31, 2015		365,000	$	70	$	85	$	94.75	NYMEX WTI
Subsequent event	'
Subsequent events	'
Schedule of three-way crude oil collar contracts that combine a long and short put with a short call	'
	In July 2014, the Company entered into the following three-way natural gas collar contracts that combine a long and short put with a short call:
	Contract Period	Mmbtu		Short Put		Long Put		Short Call		Pricing Index
	August 1, 2014 - December 31, 2015		2,590,000	$	3.5	$	4	$	4.9	NYMEX NG
	August 1, 2014 - December 31, 2015		2,590,000	$	3.5	$	4	$	4.9	NYMEX NG
	In August 2014, the Company entered into the following three-way crude oil collar contracts that combine a long and short put with a short call:
	Contract Period	Barrels		Short Put		Long Put		Short Call		Pricing Index
	January 1, 2015 - December 31, 2015		365,000	$	75	$	90	$	97	NYMEX NG
	January 1, 2015 - December 31, 2015		365,000	$	75	$	90	$	97.25	NYMEX NG

Acquisitions_Details

Acquisitions (Details) (USD $)

3 Months Ended

6 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

6 Months Ended

1 Months Ended

In Thousands, except Share data, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 27, 2014

Jun. 30, 2014

31-May-13

Oct. 04, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Aug. 31, 2013

6.125% Notes

7.75% Notes

Catarina

Catarina

Catarina

Cotulla

Wycross

Catarina, Wycross and Cotulla

Catarina, Wycross and Cotulla

Catarina, Wycross and Cotulla

Catarina, Wycross and Cotulla

Area of property acquired in Mississippi and Louisiana (in acres)

6.125% Notes

6.125% Notes

Acquisitions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of debt

'

'

$100,000

$236,000

'

'

'

'

$850,000

'

'

'

'

'

'

'

'

Shares of the Company's common stock issued in acquisition

'

'

'

'

'

'

'

'

'

'

'

11,040,000

'

'

'

'

342,760

Total purchase price allocated to assets purchased and liabilities assumed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proved oil and natural gas properties

'

'

'

'

'

'

'

428,484

'

'

265,466

215,265

'

'

'

'

'

Unproved properties

'

'

'

'

'

'

'

137,089

'

'

16,745

13,095

'

'

'

'

'

Other assets acquired

'

'

'

'

'

'

'

2,682

'

'

'

1,523

'

'

'

'

'

Fair value of assets acquired

'

'

'

'

'

'

'

568,255

'

'

282,211

229,883

'

'

'

'

'

Asset retirement obligation

-14,723

'

-14,723

'

-1,296

'

'

-14,723

'

'

-1,138

-158

'

'

'

'

'

Other liabilities assumed

'

'

'

'

'

'

'

'

'

'

-190

-113

'

'

'

'

'

Fair value of net assets acquired

'

'

'

'

'

'

'

553,532

'

'

280,883

229,612

'

'

'

'

'

Interest rate (as a percent)

'

'

'

'

'

6.13%

7.75%

'

'

6.13%

'

'

'

'

'

'

'

Unaudited pro forma combined statements of operations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenue

'

'

'

'

'

'

'

'

'

'

'

'

216,051

190,468

445,563

347,865

'

Net income (loss) attributable to common stockholders

'

'

'

'

'

'

'

'

'

'

'

'

-12,268

12,498

-7,920

11,028

'

Net income (loss) per common share, basic (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

($0.24)

$0.36

($0.16)

$0.32

'

Net income (loss) per common share, diluted (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

($0.24)

$0.34

($0.16)

$0.32

'

Revenue and revenues in excess of direct operating expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenues

151,661

59,085

286,223

90,121

'

'

'

'

'

'

'

'

54,937

8,474

109,408

8,474

'

Excess of revenues over direct operating expenses

$30,456

$11,656

$58,143

$16,273

'

'

'

'

'

'

'

'

$45,136

$4,929

$86,505

$4,929

'

Cash_and_Cash_Equivalents_Deta

Cash and Cash Equivalents (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Cash and cash equivalents	'	'	'	'
Total cash and cash equivalents	$385,871	$153,531	$226,642	$50,347
Cash at banks	'	'	'	'
Cash and cash equivalents	'	'	'	'
Total cash and cash equivalents	135,870	48,326	'	'
Money market funds	'	'	'	'
Cash and cash equivalents	'	'	'	'
Total cash and cash equivalents	$250,001	$105,205	'	'

Oil_and_Natural_Gas_Properties1

Oil and Natural Gas Properties (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Oil and Natural Gas Properties	'	'	'	'
Discount rate used to compute present value of estimated proved reserves (as a percent)	'	'	10.00%	'
Impairment expense	$0	$0	$0	$0

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 27, 2014
In Thousands, unless otherwise specified			7.75% Notes	6.125% Notes	6.125% Notes
Long-Term Debt	'	'	'	'	'
Interest rate (as a percent)	'	'	7.75%	6.13%	6.13%
Long term debt before unamortized discount	$1,450,000	'	$600,000	$850,000	'
Unamortized discount on Senior notes	-6,290	'	'	'	'
Total Long Term Debt	$1,443,710	$593,258	'	'	'

LongTerm_Debt_Details_2

Long-Term Debt (Details 2) (USD $)

3 Months Ended

6 Months Ended

0 Months Ended

1 Months Ended

0 Months Ended

0 Months Ended

6 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Sep. 18, 2013

Jun. 13, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 27, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 27, 2014

Jun. 13, 2013

Jun. 30, 2014

Jun. 13, 2013

Jun. 27, 2014

12-May-14

31-May-13

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

7.75% Notes

7.75% Notes

7.75% Notes

7.75% Notes

6.125% Notes

6.125% Notes

6.125% Notes

Revolving credit facility

First Lien Credit Agreement

Second Lien Credit Agreement

Bridge Facility

Previous First Lien Credit Agreement

Previous First Lien Credit Agreement

Previous First Lien Credit Agreement

Previous First Lien Credit Agreement

Second Amended and Restated Credit Agreement

Second Amended and Restated Credit Agreement

Second Amended and Restated Credit Agreement

Second Amended and Restated Credit Agreement

Second Amended and Restated Credit Agreement

Second Amended and Restated Credit Agreement

Second Amended and Restated Credit Agreement

Second Amended and Restated Credit Agreement

Second Amended and Restated Credit Agreement

Second Amended and Restated Credit Agreement

Prior to June 15, 2017

Prior to July 15, 2018

6.125% Notes

Term loan facility

6.125% Notes

Revolving credit facility

Revolving credit facility

Letters of credit

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Revolving credit facility

Minimum

Maximum

Alternate base rate

Alternate base rate

Alternate base rate

Eurodollar rate

Eurodollar rate

Eurodollar rate

Minimum

Maximum

Minimum

Maximum

Long-Term Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate (as a percent)

'

'

'

'

'

'

7.75%

'

6.13%

6.13%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage value of Additional Notes at which they are offered in private offering

'

'

'

'

'

'

96.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

$400,000,000

$100,000,000

'

$300,000,000

'

'

'

$500,000,000

$50,000,000

$1,500,000,000

'

'

'

'

'

'

'

'

Initial borrowing base

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

87,500,000

'

'

'

'

437,500,000

'

'

'

'

'

'

'

'

Aggregate elected commitment amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

425,000,000

'

'

'

'

'

'

'

'

Amount outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

Credit facility used

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

Percentage of increased net debt used to calculate reduction in borrowing base

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

Variable rate basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'alternate base rate

'

'

'eurodollar rate

'

'

Applicable margin percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

1.50%

'

1.50%

2.50%

Percentage of commitment fee on the unused committed amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.38%

0.50%

'

'

'

'

'

'

Current ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

Ratio of total debt outstanding to consolidated EBITDA

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

400.00%

'

'

'

'

'

'

Additional debt

'

'

'

'

200,000,000

400,000,000

'

'

850,000,000

'

'

'

'

'

'

'

'

100,000,000

'

'

'

'

'

'

'

'

'

'

'

Interest expense

17,261,000

7,069,000

30,533,000

8,153,000

'

'

'

'

'

'

'

'

'

'

3,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayment of debt using proceeds from senior note offering

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000,000

'

'

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Original discount and related offering expenses

'

'

'

'

4,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds for issuance of notes, net of original discount and related offering expenses

'

'

'

'

$188,800,000

$388,000,000

'

'

$829,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Redemption price of debt instrument (as a percent)

'

'

'

'

'

'

'

100.00%

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of debt instrument redeem under certain circumstances

'

'

'

'

'

'

'

35.00%

'

'

35.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative_Instruments_Details

Derivative Instruments (Details) (USD $)

3 Months Ended

6 Months Ended

6 Months Ended

12 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

12 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

In Thousands, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Not designated as hedges

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Crude oil

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Period from July 1, 2014 - December 31, 2014

Call

Put

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Collar Option

Collar Option

Collar Option

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Swap Purchased

Collar Option

Collar Option

Collar Option

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

Enhanced Swap Purchased

First Period from July 1, 2014 - December 31, 2014

Second Period from July 1, 2014 - December 31, 2014

Third Period from July 1, 2014 - December 31, 2014

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Third period from January 1, 2015 - December 31, 2015

Call

Call

Call

Call

Call

Call

Put

Put

Put

Put

Put

Put

Put

Put

Put

Put

Put

Put

bbl

Short

Long

First Period from July 1, 2014 - December 31, 2014

Second Period from July 1, 2014 - December 31, 2014

Third Period from July 1, 2014 - December 31, 2014

Fourth Period from July 1, 2014 - December 31, 2014

Fifth Period from July 1, 2014 - December 31, 2014

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Third period from January 1, 2015 - December 31, 2015

Fourth period from January 1, 2015 - December 31, 2015

Put

Put

Put

Put

Put

Put

Put

Put

Put

Sixth Period from July 1, 2014 - December 31, 2014

Call

Put

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Third period from January 1, 2015 - December 31, 2015

Fourth period from January 1, 2015 - December 31, 2015

Long

Long

Long

Long

Put

Put

Put

Put

First Period from July 1, 2014 - December 31, 2014

Second Period from July 1, 2014 - December 31, 2014

Third Period from July 1, 2014 - December 31, 2014

Period from July 1, 2014 - December 31, 2014

Put

Put

Put

Put

Fourth Period from July 1, 2014 - December 31, 2014

Call

Put

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Third period from January 1, 2015 - December 31, 2015

Long

Long

Long

Put

Put

Put

bbl

bbl

bbl

bbl

bbl

bbl

Short

Short

Short

Short

Short

Short

Short

Short

Short

Short

Short

Short

Long

Long

Long

Long

Long

Long

Period from July 1, 2014 - December 31, 2014

Period from July 1, 2014 - December 31, 2014

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

Long

Long

Long

Long

Long

Long

Long

Long

Long

bbl

Short

Long

bbl

bbl

bbl

bbl

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Third period from January 1, 2015 - December 31, 2015

Fourth period from January 1, 2015 - December 31, 2015

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Third period from January 1, 2015 - December 31, 2015

Fourth period from January 1, 2015 - December 31, 2015

MMBTU

MMBTU

MMBTU

MMBTU

Long

Long

Long

Long

MMBTU

Short

Long

bbl

bbl

bbl

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Third period from January 1, 2015 - December 31, 2015

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Third period from January 1, 2015 - December 31, 2015

First Period from July 1, 2014 - December 31, 2014

Second Period from July 1, 2014 - December 31, 2014

Third Period from July 1, 2014 - December 31, 2014

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Third period from January 1, 2015 - December 31, 2015

First Period from July 1, 2014 - December 31, 2014

Second Period from July 1, 2014 - December 31, 2014

Third Period from July 1, 2014 - December 31, 2014

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Third period from January 1, 2015 - December 31, 2015

First Period from July 1, 2014 - December 31, 2014

Second Period from July 1, 2014 - December 31, 2014

Third Period from July 1, 2014 - December 31, 2014

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Third period from January 1, 2015 - December 31, 2015

First Period from July 1, 2014 - December 31, 2014

Second Period from July 1, 2014 - December 31, 2014

Third Period from July 1, 2014 - December 31, 2014

Fourth Period from July 1, 2014 - December 31, 2014

Fifth Period from July 1, 2014 - December 31, 2014

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Third period from January 1, 2015 - December 31, 2015

Fourth period from January 1, 2015 - December 31, 2015

Sixth Period from July 1, 2014 - December 31, 2014

Sixth Period from July 1, 2014 - December 31, 2014

First Period from July 1, 2014 - December 31, 2014

Second Period from July 1, 2014 - December 31, 2014

Third Period from July 1, 2014 - December 31, 2014

Period from July 1, 2014 - December 31, 2014

Fourth Period from July 1, 2014 - December 31, 2014

Fourth Period from July 1, 2014 - December 31, 2014

Derivative contract covering anticipated future production

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Barrels/ Mmbtu

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184,000

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'

138,000

138,000

138,000

184,000

184,000

365,000

365,000

365,000

365,000

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184,000

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365,000

365,000

365,000

365,000

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368,000

368,000

368,000

368,000

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368,000

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2,190,000

1,095,000

730,000

'

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276,000

184,000

184,000

365,000

365,000

365,000

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Price per barrel/ Mmbtu

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75

90

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92

91.35

92.45

95.45

93.25

89.65

90.05

88.48

88.35

'

99.1

90

'

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'

91.46

93.13

92.2

91.46

75

75

75

75

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4.23

4.23

4.24

4.61

'

4.5

4

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4.44

4.4

4.5

3.75

3.75

3.75

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102.25

107.5

96.22

95

95

94.75

65

75

75

70

70

70

85

95

90

85

85

85

Current Derivative Liabilities

$27,148

'

$27,148

'

$4,623

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Reconciliation of the changes in fair value of the commodity derivatives

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Beginning fair value of commodity derivatives

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-36,397

-3,397

2,145

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Net loss on derivatives

-31,900

4,252

-41,017

624

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-40,323

-16,891

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-694

-47

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Net settlements on derivative contracts

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7,344

5,755

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673

32

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Net premiums incurred on derivative contracts

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-189

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0

5,609

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Ending fair value of commodity derivatives

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($36,397)

($3,397)

$2,145

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Derivative_Instruments_Details1

Derivative Instruments (Details 2) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Offsetting Derivative Assets:	'	'
Gross Amount of Recognized Assets	$3,227	$7,359
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-3,055	-6,055
Net Amounts Presented in the Condensed Consolidated Balance Sheets	172	1,304
Offsetting Derivative Liabilities:	'	'
Gross Amount of Recognized Assets	-39,624	-10,756
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	3,055	6,055
Net Amounts Presented in the Condensed Consolidated Balance Sheets	-36,569	-4,701
Current asset	'	'
Offsetting Derivative Assets:	'	'
Gross Amount of Recognized Assets	1,202	4,049
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-1,138	-4,049
Net Amounts Presented in the Condensed Consolidated Balance Sheets	64	'
Long-term asset	'	'
Offsetting Derivative Assets:	'	'
Gross Amount of Recognized Assets	2,025	3,310
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-1,917	-2,006
Net Amounts Presented in the Condensed Consolidated Balance Sheets	108	1,304
Current liability	'	'
Offsetting Derivative Liabilities:	'	'
Gross Amount of Recognized Assets	-28,286	-8,672
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	1,138	4,049
Net Amounts Presented in the Condensed Consolidated Balance Sheets	-27,148	-4,623
Long-term liability	'	'
Offsetting Derivative Liabilities:	'	'
Gross Amount of Recognized Assets	-11,338	-2,084
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	1,917	2,006
Net Amounts Presented in the Condensed Consolidated Balance Sheets	($9,421)	($78)

Fair_Value_of_Financial_Instru2

Fair Value of Financial Instruments (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Fair Value of Financial Instruments	'	'	'	'
Cash and cash equivalents	$385,871	$153,531	$226,642	$50,347
Recurring basis | Total Carrying Value	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Total	213,604	101,808	'	'
Recurring basis | Total Carrying Value | Swaps | Oil	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	-19,434	-2,841	'	'
Recurring basis | Total Carrying Value | Swaps | Gas	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	-189	-37	'	'
Recurring basis | Total Carrying Value | Enhanced Swaps | Oil	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	-7,785	'	'	'
Recurring basis | Total Carrying Value | Enhanced Swaps | Gas	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	205	'	'	'
Recurring basis | Total Carrying Value | Three-way collar contracts | Oil	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	-8,203	-398	'	'
Recurring basis | Total Carrying Value | Collars | Oil	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	-954	3	'	'
Recurring basis | Total Carrying Value | Collars | Gas	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	-51	22	'	'
Recurring basis | Total Carrying Value | Puts | Oil	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	14	-146	'	'
Recurring basis | Total Carrying Value | Money market funds	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Cash and cash equivalents	250,001	105,205	'	'
Recurring basis | Active Market for Identical Assets (Level 1)	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Total	250,001	105,205	'	'
Recurring basis | Active Market for Identical Assets (Level 1) | Money market funds	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Cash and cash equivalents	250,001	105,205	'	'
Recurring basis | Observable Inputs (Level 2)	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Total	-19,623	-2,878	'	'
Recurring basis | Observable Inputs (Level 2) | Swaps | Oil	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	-19,434	-2,841	'	'
Recurring basis | Observable Inputs (Level 2) | Swaps | Gas	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	-189	-37	'	'
Recurring basis | Unobservable Inputs (Level 3)	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Total	-16,774	-519	'	'
Recurring basis | Unobservable Inputs (Level 3) | Enhanced Swaps | Oil	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	-7,785	'	'	'
Recurring basis | Unobservable Inputs (Level 3) | Enhanced Swaps | Gas	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	205	'	'	'
Recurring basis | Unobservable Inputs (Level 3) | Three-way collar contracts | Oil	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	-8,203	-398	'	'
Recurring basis | Unobservable Inputs (Level 3) | Collars | Oil	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	-954	3	'	'
Recurring basis | Unobservable Inputs (Level 3) | Collars | Gas	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	-51	22	'	'
Recurring basis | Unobservable Inputs (Level 3) | Puts | Oil	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Derivative instruments	14	-146	'	'
7.75% Notes	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Interest rate (as a percent)	7.75%	'	'	'
7.75% Notes | Recurring basis | Estimated fair value	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Total	660,000	'	'	'
6.125% Notes	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Interest rate (as a percent)	6.13%	'	'	'
6.125% Notes | Recurring basis | Estimated fair value	'	'	'	'
Fair Value of Financial Instruments	'	'	'	'
Total	$875,500	'	'	'

Fair_Value_of_Financial_Instru3

Fair Value of Financial Instruments (Details 2) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Changes in the fair value of the company s oil derivative instruments classified as Level 3 in the fair value hierarchy	'	'	'	'
Gains (losses) included in earnings related to	($14,259)	$2,526	($16,225)	$893
Oil derivative instruments	'	'	'	'
Changes in the fair value of the company s oil derivative instruments classified as Level 3 in the fair value hierarchy	'	'	'	'
Beginning balance	-2,516	932	-519	3,015
Total gains (losses) included in earnings	-15,391	2,165	-17,800	151
Net settlements on derivative contracts	1,133	-94	1,545	-163
Ending balance	($16,774)	$3,003	($16,774)	$3,003

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	3 Months Ended		6 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Jun. 30, 2014	Dec. 31, 2013
Changes in the asset retirement obligation	'	'	'	'
Abandonment liability, beginning of period	$4,130	$546	$4,130	$546
Liabilities incurred during period	'	'	1,450	1,122
Acquisitions	'	'	14,723	1,296
Revisions	2,100	1,000	2,056	968
Accretion expense	'	'	267	198
Abandonment liability, end of period	'	'	$22,626	$4,130

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Aug. 31, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Aug. 31, 2013	Jun. 30, 2014
			Area of property acquired in Mississippi and Louisiana (in acres)	SOG	SOG	SOG	SOG	SR	SR
			item					Area of property acquired in Mississippi and Louisiana (in acres)	Area of property acquired in Mississippi and Louisiana (in acres)
			acre					item	item
								acre
Related Party Transactions	'	'	'	'	'	'	'	'	'
Administrative fees	'	'	'	$6,330,000	$3,479,000	$12,462,000	$5,902,000	'	'
Third party expenses	'	'	'	1,776,000	104,000	2,683,000	2,284,000	'	'
Total included in general and administrative expenses	'	'	'	8,106,000	3,583,000	15,145,000	8,186,000	'	'
Accounts payable - related entities	1,888,000	961,000	'	'	'	'	'	'	'
Area of property acquired (in acres)	'	'	'	'	'	'	'	40,000	'
Number of sellers	'	'	3	'	'	'	'	'	'
Number of third parties	'	'	2	'	'	'	'	'	'
Number of related parties	'	'	1	'	'	'	'	'	'
Ownership interest in total area of property (as a percent)	'	'	50.00%	'	'	'	'	'	'
Gross area of property acquired (in acres)	'	'	115,000	'	'	'	'	'	'
Net area of property acquired (in acres)	'	'	80,000	'	'	'	'	'	'
Cash paid	'	'	70,000,000	'	'	'	'	'	'
Common shares issued	'	'	342,760	'	'	'	'	'	'
Company valued	'	'	7,500,000	'	'	'	'	'	'
Cash consideration	'	'	'	'	'	'	'	$14,400,000	'
Obligation for working interest for partner's portion of the completed well costs, on the initial wells to be drilled within the AMI (as a percent)	'	'	'	'	'	'	'	50.00%	50.00%
Number of wells to be drilled within Area of Mutual Interest for which the entity has obligation in working interest in well costs, gross	'	'	'	'	'	'	'	3	3
Number of wells to be drilled within Area of Mutual Interest for which the entity has obligation in working interest in well costs, net	'	'	'	'	'	'	'	1.5	1.5
Additional number of wells to be drilled within Area of Mutual Interest for which the entity has obligation in working interest in well costs, gross	'	'	'	'	'	'	'	3	3
Additional number of wells to be drilled within Area of Mutual Interest for which the entity has obligation in working interest in well costs, net	'	'	'	'	'	'	'	1.5	1.5

Accrued_Liabilities_Details

Accrued Liabilities (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Accrued Liabilities	'	'
Capital expenditures	$98,989	$86,883
General and administrative costs	7,017	550
Production taxes	3,017	2,903
Ad valorem taxes	4,385	981
Lease operating expenses	7,772	8,977
Interest payable	2,372	2,161
Total accrued liabilities	$123,552	$102,455

Stockholders_Equity_Details

Stockholders' Equity (Details) (USD $)

0 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

12 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

12 Months Ended

6 Months Ended

29-May-14

Feb. 14, 2014

Feb. 12, 2014

Jun. 30, 2014

Jun. 30, 2013

Jun. 12, 2014

Sep. 18, 2013

Sep. 17, 2012

29-May-14

Feb. 14, 2014

Feb. 12, 2014

Sep. 17, 2012

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

29-May-14

Feb. 14, 2014

Feb. 12, 2014

Mar. 26, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Common Stock

Common Stock

Common Stock

Preferred stock, Convertible Perpetual Preferred Stock, Series A

Preferred stock, Convertible Perpetual Preferred Stock, Series A

Preferred stock, Convertible Perpetual Preferred Stock, Series A

Preferred stock, Convertible Perpetual Preferred Stock, Series A

Preferred stock, Convertible Perpetual Preferred Stock, Series A

Preferred stock, Convertible Perpetual Preferred Stock, Series A

Preferred stock, Convertible Perpetual Preferred Stock, Series A

Preferred stock, Convertible Perpetual Preferred Stock, Series B

Preferred stock, Convertible Perpetual Preferred Stock, Series B

Preferred stock, Convertible Perpetual Preferred Stock, Series B

Preferred stock, Convertible Perpetual Preferred Stock, Series B

Preferred stock, Convertible Perpetual Preferred Stock, Series B

Preferred stock, Convertible Perpetual Preferred Stock, Series B

Preferred stock, Convertible Perpetual Preferred Stock, Series B

item

Minimum

item

Minimum

Stockholders' Equity

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'

'

'

Number of shares issued

'

'

'

'

'

5,000,000

11,040,000

'

'

'

'

3,000,000

'

'

'

'

'

'

4,500,000

'

'

'

Number of shares issued pursuant to the exercise of over-allotment option by underwriters

'

'

'

'

'

'

1,440,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issue price (in dollars per share)

'

'

'

'

'

$35.25

$23

'

'

'

'

$50

'

'

'

'

'

'

$50

'

'

'

Net proceeds from public offering of shares of common stock

'

'

'

$167,591,000

'

$167,600,000

$241,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from the private placement of preferred stock

'

'

'

'

225,000,000

'

'

'

'

'

'

144,500,000

'

'

'

'

'

'

216,600,000

'

'

'

Underwriters' fees and offering expenses

'

'

'

8,659,000

8,439,000

8,700,000

12,500,000

'

'

'

'

5,500,000

'

'

'

'

'

'

8,400,000

'

'

'

Conversion ratio (in shares)

'

'

'

'

'

'

'

'

'

2.325

2.325

2.325

'

'

'

'

2.337

2.337

2.337

'

'

'

Conversion price (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

$21.51

'

'

'

'

'

'

$21.40

'

'

'

Number of shares of common stock to be issued if all preferred shares are converted

'

'

'

'

'

'

'

4,772,086

'

'

'

'

'

'

'

'

'

'

8,747,742

'

'

'

Annual dividend (as a percent)

'

'

'

'

'

'

'

'

'

'

'

4.88%

4.88%

4.88%

'

'

'

'

6.50%

6.50%

6.50%

'

Liquidation preference (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

$50

'

'

'

'

'

'

$50

'

'

'

Dividends accrued or accumulated

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

Period of failure to pay dividend, resulting into appointment of board of directors

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year 6 months

'

'

'

'

'

'

'1 year 6 months

Number of directors who can be elected upon failure to pay dividend for six or more quarters

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

2

'

'

Condition for automatic conversion: Closing sale price of common stock as a percentage of conversion price for specified period prior to conversion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

130.00%

'

'

'

'

'

'

130.00%

Preferred stock converted into shares of common stock

'

'

'

'

'

'

'

'

166,025

947,490

947,490

'

'

'

'

210,820

756,850

756,850

'

'

'

'

Fair value of the shares of common stock issued in excess of the carrying value of the Series A Preferred Stock and Series B Preferred Stock redeemed

$3,100,000

$13,900,000

$13,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares of common stock issued upon conversion of preferred stock

'

'

'

'

'

'

'

'

418,715

2,425,574

2,425,574

'

'

'

'

553,980

2,021,066

2,021,066

'

'

'

'

Stockholders_Equity_Details_2

Stockholders' Equity (Details 2) (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
Earnings (Loss) Per Share	'	'	'	'
Net income (loss)	($12,158)	$8,890	($8,713)	$8,816
Preferred stock dividends	-7,132	-5,484	-25,325	-7,556
Net income allocable to participating securities	'	-159	'	-56
Net income (loss) attributable to common stockholders	($19,290)	$3,247	($34,038)	$1,204
Weighted average number of unrestricted outstanding common shares used to calculate basic net income (loss) per share	50,602	33,117	48,825	33,108
Denominator for diluted net income (loss) per common share	50,602	33,117	48,825	33,108
Net income (loss) per common share - basic and diluted (in dollars per share)	($0.38)	$0.10	($0.70)	$0.04

Stockholders_Equity_Details_3

Stockholders' Equity (Details 3) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Restricted stock	'	'	'	'
Anti-dilutive common stock	'	'	'	'
Anti-dilutive common stock	423,771	208,130	829,375	539,141
Net income allocable to participating securities	$0	'	$0	'
Convertible Preferred Stock	'	'	'	'
Anti-dilutive common stock	'	'	'	'
Anti-dilutive common stock	13,253,510	17,491,500	14,502,257	12,466,950

StockBased_Compensation_Detail

Stock-Based Compensation (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Stock-Based Compensation	'	'	'	'
Common stock available for incentive awards, as a percentage of the issued and outstanding shares of common stock	15.00%	'	15.00%	'
Restricted common stock	'	'	'	'
Stock-Based Compensation	'	'	'	'
Total stock-based compensation expense	$15,943,000	$4,578,000	$25,878,000	$7,712,000
Additional disclosure related to compensation cost	'	'	'	'
Closing price of common stock (in dollars per share)	$37.59	'	$37.59	'
Unrecognized compensation costs related to non-vested restricted shares outstanding	68,000,000	'	68,000,000	'
Expected average period for recognition of unrecognized compensation costs related to non-vested shares	'	'	'1 year 10 months 24 days	'
Number of Non-Vested Shares	'	'	'	'
Non-vested common stock at the beginning of the period (in shares)	'	'	1,758,000	'
Granted (in shares)	'	'	1,646,000	'
Vested (in shares)	'	'	-636,000	'
Forfeited (in shares)	'	'	-309,000	'
Non-vested common stock at the end of the period (in shares)	2,459,000	'	2,459,000	'
Shares available for future issuance to participants	4,900,000	'	4,900,000	'
Restricted common stock | Directors	'	'	'	'
Stock-Based Compensation	'	'	'	'
Total stock-based compensation expense	262,000	138,000	560,000	231,000
Restricted common stock, not rescinded and cancelled | Non-employees	'	'	'	'
Stock-Based Compensation	'	'	'	'
Total stock-based compensation expense	$15,681,000	$4,440,000	$25,318,000	$7,481,000

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Income Taxes	'	'	'	'
Federal statutory corporate income tax rate (as a percent)	35.00%	'	35.00%	'
Effective tax rate (as a percent)	'	0.00%	34.90%	0.00%
Net operating loss carryforwards	$660,500,000	'	$660,500,000	'
Change in the valuation allowance	0	'	0	'
Uncertain tax positions	$0	'	$0	'

Commitments_and_Contingencies_

Commitments and Contingencies (Details)	0 Months Ended	1 Months Ended	6 Months Ended
	Dec. 16, 2013	Aug. 31, 2013	Jun. 30, 2014	Jun. 30, 2014
	item	Area of property acquired in Mississippi and Louisiana (in acres)	Area of property acquired in Mississippi and Louisiana (in acres)	Catarina
		SR	SR	item
		item	item	sqft
Commitments	'	'	'	'
Number of derivative actions filed	3	'	'	'
Obligation for working interest for partner's portion of the completed well costs, on the initial wells to be drilled within the AMI (as a percent)	'	50.00%	50.00%	'
Number of wells to be drilled within Area of Mutual Interest for which the entity has obligation in working interest in well costs, gross	'	3	3	'
Number of wells to be drilled within Area of Mutual Interest for which the entity has obligation in working interest in well costs, net	'	1.5	1.5	'
Additional number of wells to be drilled within Area of Mutual Interest for which the entity has obligation in working interest in well costs, gross	'	3	3	'
Additional number of wells to be drilled within Area of Mutual Interest for which the entity has obligation in working interest in well costs, net	'	1.5	1.5	'
Area of undeveloped acreage acquired (in acres)	'	'	'	77,000
Maximum number of wells to be drilled in each annual period commencing July 1, 2014	'	'	'	50
Minimum number of wells to be drilled in any consecutive 120 days period in order to continue to maintain rights to any future undeveloped acreage	'	'	'	1
Consecutive days period over which at least one well can be drilled in order to continue to maintain rights to any future undeveloped acreage	'	'	'	'120 days
Maximum number of wells that can be carried over to satisfy part of the 50 well requirement in the subsequent annual period on a well for well basis	'	'	'	30

Subsidiary_Guarantors_Details

Subsidiary Guarantors (Details) (USD $)	6 Months Ended
	Jun. 30, 2014
Subsidiary Guarantors	'
Ownership interest in Subsidiaries (as a percent)	100.00%
Amount of independent assets	$0
Amount of independent operations	$0

Subsequent_Events_Details

Subsequent Events (Details) (Not designated as hedges)

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Aug. 31, 2014

Aug. 31, 2014

Aug. 31, 2014

Aug. 31, 2014

Aug. 31, 2014

Aug. 31, 2014

Aug. 31, 2014

Aug. 31, 2014

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Crude oil

Crude oil

Crude oil

Crude oil

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

First period from January 1, 2015 - December 31, 2015

First period from January 1, 2015 - December 31, 2015

First period from January 1, 2015 - December 31, 2015

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

First period from January 1, 2015 - December 31, 2015

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

Three-way crude oil collar contracts

bbl

Call

Put

Put

bbl

Call

Put

Put

Swaps

Put

Swaps

Put

First period from August 1, 2014 - December 31, 2015

First period from August 1, 2014 - December 31, 2015

First period from August 1, 2014 - December 31, 2015

First period from August 1, 2014 - December 31, 2015

Second period from August 1, 2014 - December 31, 2015

Second period from August 1, 2014 - December 31, 2015

Second period from August 1, 2014 - December 31, 2015

Second period from August 1, 2014 - December 31, 2015

First period from January 1, 2015 - December 31, 2015

First period from January 1, 2015 - December 31, 2015

First period from January 1, 2015 - December 31, 2015

First period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Second period from January 1, 2015 - December 31, 2015

Short

Short

Long

Short

Short

Long

bbl

Long

bbl

Long

bbl

Call

Put

Put

bbl

Call

Put

Put

bbl

Call

Put

Put

bbl

Call

Put

Put

Swaps

Swaps

Short

Short

Long

Short

Short

Long

Short

Short

Long

Short

Short

Long

Subsequent events

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Barrels/ Mmbtu

365,000

'

'

'

365,000

'

'

'

365,000

'

365,000

'

2,590,000

'

'

'

2,590,000

'

'

'

365,000

'

'

'

365,000

'

'

'

Price per barrel/ Mmbtu

'

95

70

85

'

95

70

85

'

89.65

'

90.05

'

4.9

3.5

4

'

4.9

3.5

4

'

97

75

90

'

97.25

75

90