SandRidge Energy (SD) 10-K 30 Mar 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Mar. 23, 2016	Jun. 30, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	SANDRIDGE ENERGY INC
Entity Central Index Key	1,349,436
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Amendment Flag	false
Entity Public Float			$ 447.7
Entity Common Stock, Shares Outstanding		718,226,053

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Current assets
Cash and cash equivalents	$ 435,588	$ 181,253
Accounts receivable, net	127,387	330,077
Derivative contracts	84,349	291,414
Prepaid expenses	6,833	7,981
Other current assets	19,931	21,193
Total current assets	674,088	831,918
Oil and natural gas properties, using full cost method of accounting
Proved (includes development and project costs excluded from amortization of $34.6 million and $53.6 million at December 31, 2015 and 2014, respectively)	12,529,681	11,707,147
Unproved	363,149	290,596
Less: accumulated depreciation, depletion and impairment	(11,149,888)	(6,359,149)
Net oil and natural gas properties capitalized costs	1,742,942	5,638,594
Other property, plant and equipment, net	491,760	576,463
Derivative contracts	0	47,003
Other assets	82,365	165,247
Total assets	2,991,155	7,259,225
Current liabilities
Accounts payable and accrued expenses	428,417	683,392
Derivative contracts	573	0
Asset retirement obligations	8,399	0
Deferred tax liability	0	95,843
Other current liabilities	0	5,216
Total current liabilities	437,389	784,451
Long-term debt	3,631,506	3,195,436
Asset retirement obligations	95,179	54,402
Other long-term obligations	14,814	15,116
Total liabilities	$ 4,178,888	$ 4,049,405
Commitments and contingencies (Note 15)
Preferred stock, $0.001 par value, 50,000 shares authorized
Common stock, $0.001 par value; 1,800,000 shares authorized, 635,584 issued and 633,471 outstanding at December 31, 2015; 800,000 shares authorized, 485,932 issued and 484,819 outstanding at December 31, 2014	$ 630	$ 477
Additional paid-in capital	5,301,136	5,204,024
Additional paid-in capital—stockholder receivable	(1,250)	(2,500)
Treasury stock, at cost	(5,742)	(6,980)
Accumulated deficit	(6,992,697)	(3,257,202)
Total SandRidge Energy, Inc. stockholders’ (deficit) equity	(1,697,917)	1,937,825
Noncontrolling interest	510,184	1,271,995
Total stockholders’ (deficit) equity	(1,187,733)	3,209,820
Total liabilities and stockholders’ (deficit) equity	2,991,155	7,259,225
8.5% Convertible perpetual preferred stock; 2,650 shares issued and outstanding at December 31, 2015 and 2014; aggregate liquidation preference of $265,000
Preferred stock, $0.001 par value, 50,000 shares authorized
Preferred stock	3	3
7.0% Convertible perpetual preferred stock; 2,770 shares issued and outstanding at December 31, 2015, aggregate liquidation preference of $277,000; 3,000 shares issued and outstanding at December 31, 2014, aggregate liquidation preference of $300,000
Preferred stock, $0.001 par value, 50,000 shares authorized
Preferred stock	$ 3	$ 3

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Development and project costs excluded from amortization	$ 34,600	$ 53,600
Preferred stock, par value (in dollars per share)	$ 0.001	$ 0.001
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares authorized (in shares)	1,800,000,000	800,000,000
Common stock, issued (in shares)	635,584,000	485,932,000
Common stock, outstanding (in shares)	633,471,000	484,819,000
8.5% Convertible perpetual preferred stock; 2,650 shares issued and outstanding at December 31, 2015 and 2014; aggregate liquidation preference of $265,000
Preferred stock, dividend rate, percentage	8.50%	8.50%
Preferred stock, shares issued (in shares)	2,650,000	2,650,000
Preferred stock, shares outstanding (in shares)	2,650,000	2,650,000
Preferred stock, aggregate liquidation preference	$ 265,000	$ 265,000
7.0% Convertible perpetual preferred stock; 2,770 shares issued and outstanding at December 31, 2015, aggregate liquidation preference of $277,000; 3,000 shares issued and outstanding at December 31, 2014, aggregate liquidation preference of $300,000
Preferred stock, dividend rate, percentage	7.00%	7.00%
Preferred stock, shares issued (in shares)	2,770,000	3,000,000
Preferred stock, shares outstanding (in shares)	2,770,000	3,000,000
Preferred stock, aggregate liquidation preference	$ 277,000	$ 300,000

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenues
Oil, natural gas and NGL	$ 707,434	$ 1,420,879	$ 1,820,278
Drilling and services	22,124	76,088	66,586
Midstream and marketing	33,809	55,658	58,304
Construction contract	0	0	23,349
Other	5,342	6,133	14,871
Total revenues	768,709	1,558,758	1,983,388
Expenses
Production	308,701	346,088	516,427
Production taxes	15,440	31,731	32,292
Cost of sales	24,394	56,155	57,118
Midstream and marketing	26,819	49,905	53,644
Construction contract	0	0	23,349
Depreciation and depletion—oil and natural gas	319,913	434,295	567,732
Depreciation and amortization—other	47,382	59,636	62,136
Accretion of asset retirement obligations	4,477	9,092	36,777
Impairment	4,534,689	192,768	26,280
General and administrative	137,715	113,991	207,920
Employee termination benefits	12,451	8,874	122,505
(Gain) loss on derivative contracts	(73,061)	(334,011)	47,123
Loss on settlement of contract	50,976	0	0
Loss on sale of assets	1,491	10	399,086
Total expenses	5,411,387	968,534	2,152,389
(Loss) income from operations	(4,642,678)	590,224	(169,001)
Other (expense) income
Interest expense	(321,421)	(244,109)	(270,234)
Gain (loss) on extinguishment of debt	641,131	0	(82,005)
Other income, net	2,040	3,490	12,445
Total other income (expense)	321,750	(240,619)	(339,794)
(Loss) income before income taxes	(4,320,928)	349,605	(508,795)
Income tax expense (benefit)	123	(2,293)	5,684
Net (loss) income	(4,321,051)	351,898	(514,479)
Less: net (loss) income attributable to noncontrolling interest	(623,506)	98,613	39,410
Net (loss) income attributable to SandRidge Energy, Inc.	(3,697,545)	253,285	(553,889)
Preferred stock dividends	37,950	50,025	55,525
(Loss applicable) income available to SandRidge Energy, Inc. common stockholders	$ (3,735,495)	$ 203,260	$ (609,414)
(Loss) earnings per share
Basic (in dollars per share)	$ (7.16)	$ 0.42	$ (1.27)
Diluted (in dollars per share)	$ (7.16)	$ 0.42	$ (1.27)
Weighted average number of common shares outstanding
Basic (in shares)	521,936	479,644	481,148
Diluted (in shares)	521,936	499,743	481,148

Consolidated Statements of Chan

Consolidated Statements of Changes in Stockholders’ Equity (Deficit) - USD ($) shares in Thousands, $ in Thousands	Total	Convertible Perpetual Preferred Stock	Common Stock	Additional Paid-In Capital	Treasury Stock	Accumulated Deficit	Non-controlling Interest
Beginning Balance at Dec. 31, 2012	$ 3,862,455	$ 8	$ 476	$ 5,228,019	$ (8,602)	$ (2,851,048)	$ 1,493,602
Beginning Balance (in shares) at Dec. 31, 2012		7,650
Beginning Balance (in shares) at Dec. 31, 2012			490,359
Increase (Decrease) in Stockholders' Equity
Sale of royalty trust units	28,985			7,289			21,696
Distributions to noncontrolling interest owners	(206,470)						(206,470)
Contributions from noncontrolling interest owners	1,579						1,579
Purchase of treasury stock	(30,126)				(30,126)
Retirement of treasury stock	0			(30,126)	30,126
Stock purchases/distributions, net of distributions/purchases - retirement plans (in shares)			(99)
Stock purchases/distributions, net of distributions/purchases - retirement plans	(435)			(267)	(168)
Stock-based compensation	88,397			88,397
Stock-based compensation excess tax provision	(4)			(4)
Payment received on shareholder receivable	1,250			1,250
Issuance of restricted stock awards, net of cancellations (in shares)			30
Issuance of restricted stock awards, net of cancellations	0		$ 7	(7)
Common stock issued for debt	0
Net (loss) income	(514,479)					(553,889)	39,410
Convertible perpetual preferred stock dividends	(55,525)					(55,525)
Ending Balance (in shares) at Dec. 31, 2013		7,650
Ending Balance (in shares) at Dec. 31, 2013			490,290
Ending Balance at Dec. 31, 2013	3,175,627	$ 8	$ 483	5,294,551	(8,770)	(3,460,462)	1,349,817
Increase (Decrease) in Stockholders' Equity
Sale of royalty trust units	22,119			4,091			18,028
Distributions to noncontrolling interest owners	(193,807)						(193,807)
Purchase of treasury stock	(6,373)				(6,373)
Retirement of treasury stock	0			(6,373)	6,373
Stock purchases/distributions, net of distributions/purchases - retirement plans (in shares)			206
Stock purchases/distributions, net of distributions/purchases - retirement plans	9			(1,781)	1,790
Stock-based compensation	23,665			23,665
Stock-based compensation excess tax benefit	14			14
Payment received on shareholder receivable	1,250			1,250
Issuance of restricted stock awards, net of cancellations (in shares)			3,311
Issuance of restricted stock awards, net of cancellations	0		$ 3	(3)
Common stock issued for debt	0
Acquisition of ownership interest	(2,730)			(2,074)			(656)
Repurchase of common stock (in shares)			(27,411)
Repurchase of common stock	(111,827)		$ (27)	(111,800)
Conversion of preferred stock to common stock (in shares)		(2,000)	18,423
Conversion of preferred stock to common stock	0	$ (2)	$ 18	(16)
Net (loss) income	351,898					253,285	98,613
Convertible perpetual preferred stock dividends	$ (50,025)					(50,025)
Ending Balance (in shares) at Dec. 31, 2014		5,650
Ending Balance (in shares) at Dec. 31, 2014	484,819		484,819
Ending Balance at Dec. 31, 2014	$ 3,209,820	$ 6	$ 477	5,201,524	(6,980)	(3,257,202)	1,271,995
Increase (Decrease) in Stockholders' Equity
Distributions to noncontrolling interest owners	(138,305)						(138,305)
Purchase of treasury stock	(2,428)				(2,428)
Retirement of treasury stock	0			(2,428)	2,428
Stock purchases/distributions, net of distributions/purchases - retirement plans (in shares)			(1,000)
Stock purchases/distributions, net of distributions/purchases - retirement plans	322			(916)	1,238
Stock-based compensation	21,123			21,123
Payment received on shareholder receivable	1,250			1,250
Issuance of restricted stock awards, net of cancellations (in shares)			1,514
Issuance of restricted stock awards, net of cancellations	$ 0		$ 5	(5)
Common stock issued for debt (in shares)	92,800		120,881
Common stock issued for debt	$ 63,299		$ 121	63,178
Conversion of preferred stock to common stock (in shares)		(230)	2,968
Conversion of preferred stock to common stock	0		$ 3	(3)
Net (loss) income	(4,321,051)					(3,697,545)	(623,506)
Convertible perpetual preferred stock dividends (in shares)			24,289
Convertible perpetual preferred stock dividends	$ (21,763)		$ 24	16,163		(37,950)
Ending Balance (in shares) at Dec. 31, 2015		5,420
Ending Balance (in shares) at Dec. 31, 2015	633,471		633,471
Ending Balance at Dec. 31, 2015	$ (1,187,733)	$ 6	$ 630	$ 5,299,886	$ (5,742)	$ (6,992,697)	$ 510,184

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income	$ (4,321,051)	$ 351,898	$ (514,479)
Adjustments to reconcile net (loss) income to net cash provided by operating activities
Depreciation, depletion and amortization	367,295	493,931	629,868
Accretion of asset retirement obligations	4,477	9,092	36,777
Impairment	4,534,689	192,768	26,280
Debt issuance costs amortization	11,884	9,425	10,091
Amortization of discount, net of premium, on long-term debt	3,130	529	1,036
(Gain) loss on extinguishment of debt	(641,131)	0	82,005
Write off of debt issuance costs	7,108	0	0
Deferred income tax provision	0	0	3,842
Loss on long-term debt derivatives	10,377	0	0
Cash paid for early conversion of convertible notes	(32,741)	0	0
(Gain) loss on derivative contracts	(73,061)	(334,011)	47,123
Cash received (paid) on settlement of derivative contracts	327,702	11,796	(5,879)
Loss on settlement of contract	50,976	0	0
Cash paid on settlement of contract	(24,889)	0	0
Loss on sale of assets	1,491	10	399,086
Stock-based compensation	18,380	19,994	85,270
Other	1,351	407	3,929
Changes in operating assets and liabilities increasing (decreasing) cash
Receivables	201,907	(63,492)	90,048
Costs in excess of billings	0	0	11,229
Prepaid expenses	1,148	9,549	(7,934)
Other current assets	12,710	3,164	(3,269)
Other assets and liabilities, net	2,239	(1,132)	5,777
Accounts payable and accrued expenses	(86,470)	(66,492)	101,453
Asset retirement obligations	(3,984)	(16,322)	(133,623)
Net cash provided by operating activities	373,537	621,114	868,630
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures for property, plant and equipment	(879,201)	(1,553,332)	(1,496,731)
Acquisitions of assets	216,943	18,384	17,028
Proceeds from sale of assets	56,504	714,475	2,584,115
Net cash (used in) provided by investing activities	(1,039,640)	(857,241)	1,070,356
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from borrowings	2,065,000	0	0
Repayments of borrowings	(939,466)	0	(1,115,500)
Premium on debt redemption	0	0	(61,997)
Debt issuance costs	(53,244)	(3,947)	(91)
Proceeds from the sale of royalty trust units	0	22,119	28,985
Noncontrolling interest distributions	(138,305)	(193,807)	(206,470)
Noncontrolling interest contributions	0	0	1,579
Acquisition of ownership interest	0	(2,730)	0
Stock-based compensation excess tax benefit	0	14	(4)
Purchase of treasury stock	(3,535)	(8,702)	(32,976)
Repurchase of common stock	0	(111,827)	0
Dividends paid—preferred	(11,262)	(55,525)	(55,525)
Payment received on shareholder receivable	1,250	1,250	1,250
Cash (paid) received on settlement of financing derivative contracts	0	(44,128)	6,660
Net cash provided by (used in) financing activities	920,438	(397,283)	(1,434,089)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	254,335	(633,410)	504,897
CASH AND CASH EQUIVALENTS, beginning of year	181,253	814,663	309,766
CASH AND CASH EQUIVALENTS, end of year	$ 435,588	$ 181,253	$ 814,663

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Nature of Business. SandRidge Energy, Inc. is an energy company with a principal focus on exploration and production activities in the Mid-Continent region of the United States. The Company owns and operates additional interests in west Texas and the Rockies in Colorado. The Company also operates businesses and infrastructure systems that are complementary to its primary exploration and production activities, including gas gathering and processing facilities, marketing operations, a saltwater gathering and disposal system, an electrical transmission system and a drilling and related oilfield services business. Principles of Consolidation. The consolidated financial statements include the accounts of the Company and its wholly owned or majority owned subsidiaries and variable interest entities (“VIEs”) for which the Company is the primary beneficiary. Noncontrolling interest represents third-party ownership interests in the Company’s subsidiaries and consolidated VIEs and is included as a component of equity in the consolidated balance sheets and consolidated statements of changes in equity. All significant intercompany accounts and transactions have been eliminated in consolidation. Going Concern. The Company depends on cash flows from operating activities and, as necessary and available, borrowings under its senior secured revolving credit facility (the “senior credit facility”) to fund its capital expenditures. Additionally, the Company historically has used proceeds from the issuance of equity and debt securities in the capital markets and from sales or other monetizations of assets to fund its capital expenditures. The market price for oil, natural gas and natural gas liquids (“NGLs”) decreased significantly beginning in the fourth quarter of 2014, continuing throughout 2015, and into 2016. The decrease in the market price for production directly reduces the Company’s cash flow from operations and indirectly impacts its other potential sources of funds described above. As discussed in Note 22 , the Company borrowed all of its remaining available capacity under the senior credit facility in January 2016 and in March 2016, the lenders under the senior credit facility elected to reduce the borrowing base to $340.0 million . On March 21, 2016, the Company notified the administrative agent that the Company would submit for the administrative agent’s consideration proposed additional oil and gas properties to serve as collateral under the senior credit facility sufficient to support a borrowing base of $500.0 million . Additionally, the Company notified the administrative agent that it believed the currently pledged assets are sufficient to support a borrowing base of $500.0 million and reserved the right to exercise all other options available to remedy the borrowing base deficiency, if any. The Company has until April 20, 2016 to submit such additional properties. Lower market prices for production may result in further reductions to the borrowing base under the senior credit facility or higher borrowing costs from other potential sources of financing as the Company’s borrowing capacity and borrowing costs are generally related to the value of the Company’s estimated proved reserves. The weakness in pricing may also impact the Company’s ability to negotiate asset monetizations at acceptable prices. As a result of the impacts to the Company’s financial position resulting from declining industry conditions and in consideration of the substantial amount of long-term debt outstanding, the Company has engaged advisors to assist with the evaluation of strategic alternatives, which may include, but not be limited to, seeking a restructuring, amendment or refinancing of existing debt through a private restructuring or reorganization under Chapter 11 of the Bankruptcy Code. However, there can be no assurances that the Company will be able to successfully restructure its indebtedness, improve its financial position or complete any strategic transactions. As a result of these uncertainties and the likelihood of a restructuring or reorganization, management has concluded that there is substantial doubt regarding the Company’s ability to continue as a going concern as it is currently structured. As a result, the report of the Company’s independent registered public accounting firm that accompanies these consolidated financial statements for the year ended December 31, 2015 contains an explanatory paragraph regarding the substantial doubt about the Company’s ability to continue as a going concern, which under the terms of the senior credit facility may result in an event of default. If the Company does not obtain a waiver of this requirement or otherwise cure this event within 30 calendar days of the issuance of these financial statements, the lenders under the senior credit facility will be able to accelerate maturity of the debt. Any acceleration of the obligations under the senior credit facility would result in a cross-default and potential acceleration of the maturity of the Company’s other outstanding long-term debt. These defaults create additional uncertainty associated with the Company’s ability to repay its outstanding long-term debt obligations as they become due and further reinforces the substantial doubt over the Company’s ability to continue as a going concern. The consolidated financial statements have been prepared on a going concern basis of accounting, which contemplates continuity of operations, realization of assets and satisfaction of liabilities and commitments in the normal course of business. The consolidated financial statements do not reflect any adjustments that might result if the Company is unable to continue as a going concern. Variable Interest Entities. An entity is referred to as a VIE if it possesses one of the following criteria: (i) it is thinly capitalized, (ii) the residual equity holders do not control the entity, (iii) the equity holders are shielded from economic losses, (iv) the equity holders do not participate fully in the entity’s residual economics, or (v) the entity was established with non-substantive voting interests. The Company consolidates a VIE when it has determined it is the primary beneficiary, which requires significant judgment. The primary beneficiary of a VIE is that variable interest holder possessing a controlling financial interest through (i) its power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and (ii) its obligation to absorb losses or its right to receive benefits from the VIE that could potentially be significant to the VIE. In order to determine whether the Company owns a variable interest in a VIE and the significance of the variable interest, the Company performs a qualitative analysis of the entity’s design, organizational structure, primary decision makers and related financial agreements. In addition to the VIEs that the Company consolidates, until October 2015, the Company also held a variable interest in another VIE that it did not consolidate as it was determined that the Company is not the primary beneficiary. The Company monitors both consolidated and unconsolidated VIEs to determine if any events have occurred that could cause the primary beneficiary to change. See Note 4 for discussion of the Company’s significant associated VIEs. Reclassifications. Certain reclassifications have been made to the prior period financial statements to conform to the current period presentation. These reclassifications have no effect on the Company’s previously reported results of operations. Use of Estimates. The preparation of the consolidated financial statements in conformity with accounting principles generally accepted in the United States of America 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 more significant areas requiring the use of assumptions, judgments and estimates include: oil, natural gas and NGL reserves; cash flow estimates used in the valuations of guarantees; impairment tests of long-lived assets; depreciation, depletion and amortization; asset retirement obligations; determinations of significant alterations to the full cost pool and related estimates of fair value used to allocate the full cost pool net book value to divested properties, as necessary; income taxes; valuation of derivative instruments; contingencies; and accrued revenue and related receivables. Although management believes these estimates are reasonable, actual results could differ significantly. Cash and Cash Equivalents. The Company considers all highly-liquid instruments with an original maturity of three months or less to be cash equivalents as these instruments are readily convertible to known amounts of cash and bear insignificant risk of changes in value due to their short maturity period. Accounts Receivable, Net. The Company has receivables for sales of oil, natural gas and NGLs, as well as receivables related to the exploration, production and treating services for oil and natural gas. An allowance for doubtful accounts has been established based on management’s review of the collectability of the receivables in light of historical experience, the nature and volume of the receivables and other subjective factors. Accounts receivable are charged against the allowance, upon approval by management, when they are deemed uncollectible. Refer to Note 6 for further information on the Company’s accounts receivable and allowance for doubtful accounts. Fair Value of Financial Instruments. Certain of the Company’s financial assets and liabilities are measured at fair value. Fair value represents the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. The Company’s financial instruments, not otherwise recorded at fair value, consist primarily of cash, trade receivables, trade payables and long-term debt. The carrying value of cash, trade receivables and trade payables are considered to be representative of their respective fair values due to the short-term maturity of these instruments. See Note 5 for further discussion of the Company’s fair value measurements. Fair Value of Non-financial Assets and Liabilities. The Company also applies fair value accounting guidance to initially, or as events dictate, measure non-financial assets and liabilities such as those obtained through business acquisitions, property, plant and equipment and asset retirement obligations. These assets and liabilities are subject to fair value adjustments only in certain circumstances and are not subject to recurring revaluations. Fair value may be estimated using comparable market data, a discounted cash flow method, or a combination of the two as considered appropriate based on the circumstances. Under the discounted cash flow method, estimated future cash flows are based on management’s expectations for the future and include estimates of future oil and natural gas production or other applicable sales estimates, operational costs and a risk-adjusted discount rate. The Company may use the present value of estimated future cash inflows and/or outflows or third-party offers or prices of comparable assets with consideration of current market conditions to value its non-financial assets and liabilities when circumstances dictate determining fair value is necessary. Given the significance of the unobservable nature of a number of the inputs, these are considered Level 3 on the fair value hierarchy discussed in Note 5 . Derivative Financial Instruments. To manage risks related to fluctuations in prices attributable to its expected oil and natural gas production, the Company enters into oil and natural gas derivative contracts. Entrance into such contracts is dependent upon prevailing or anticipated market conditions. The Company may also, from time to time, enter into interest rate swaps in order to manage risk associated with its exposure to variable interest rates. Additionally, the Company has derivatives related to its 8.75% Senior Secured Notes due 2020 (“Senior Secured Notes”) and its 8.125% Convertible Senior Notes due 2022 and 7.5% Convertible Senior Notes due 2023 (collectively, “Convertible Senior Unsecured Notes”) that are recorded at fair value each reporting period. Refer to Notes 5 and 13 for further information on derivatives associated with the Company’s long-term debt. The Company recognizes its derivative instruments as either assets or liabilities at fair value with changes in fair value recognized in earnings unless designated as a hedging instrument with specific hedge accounting criteria having been met. The Company has elected not to designate price risk management activities as accounting hedges under applicable accounting guidance, and, accordingly, accounts for its commodity derivative contracts at fair value with changes in fair value reported currently in earnings. The Company nets derivative assets and liabilities whenever it has a legally enforceable master netting agreement with the counterparty to a derivative contract. The related cash flow impact of the Company’s derivative activities are reflected as cash flows from operating activities unless the derivative contract contains a significant financing element, in which case, cash settlements are classified as cash flows from financing activities in the consolidated statements of cash flows. See Note 13 for further discussion of the Company’s derivatives. Oil and Natural Gas Operations. The Company uses the full cost method to account for its oil and natural gas properties. Under full cost accounting, all costs directly associated with the acquisition, exploration and development of oil, natural gas and NGL reserves are capitalized into a full cost pool. These capitalized costs include costs of unproved properties and internal costs directly related to the Company’s acquisition, exploration and development activities and capitalized interest. The Company capitalized internal costs of $45.1 million , $55.4 million and $74.7 million to the full cost pool during the years ended December 31, 2015 , 2014 and 2013 , respectively. Capitalized costs are amortized using the unit-of-production method. Under this method, depreciation and depletion is computed at the end of each quarter by multiplying total production for the quarter by a depletion rate. The depletion rate is determined by dividing the total unamortized cost base plus future development costs by net equivalent proved reserves at the beginning of the quarter. Costs associated with unproved properties are excluded from the amortizable cost base until a determination has been made as to the existence of proved reserves. Unproved properties are reviewed at the end of each quarter to determine whether the costs incurred should be reclassified to the full cost pool and, thereby, subjected to amortization. The costs associated with unproved properties relate primarily to costs to acquire unproved acreage. Unproved leasehold costs are transferred to the amortization base with the costs of drilling the related well upon determination of the existence of proved reserves or upon impairment of a lease. All items classified as unproved property are assessed, on an individual basis or as a group if properties are individually insignificant, on a quarterly basis for possible impairment or reduction in value. The assessment includes consideration of various factors, including, but not limited to, the following: intent to drill; remaining lease term; geological and geophysical evaluations; drilling results and activity; assignment of proved reserves; and economic viability of development if proved reserves are assigned. During any period in which these factors indicate an impairment, all or a portion of the associated leasehold costs are transferred to the full cost pool and become subject to amortization. Costs of seismic data are allocated to various unproved leaseholds and transferred to the amortization base with the associated leasehold costs on a specific project basis. Under the full cost method of accounting, total capitalized costs of oil and natural gas properties, net of accumulated depreciation, depletion and impairment, less related deferred income taxes may not exceed an amount equal to the present value of future net revenues from proved reserves, discounted at 10% per annum, plus the lower of cost or fair value of unproved properties, plus estimated salvage value, less the related tax effects (the “ceiling limitation”). A ceiling limitation calculation is performed at the end of each quarter. If total capitalized costs, net of accumulated depreciation, depletion and impairment, less related deferred taxes are greater than the ceiling limitation, a write-down or impairment of the full cost pool is required. A write-down of the carrying value of the full cost pool is a non-cash charge that reduces earnings and impacts stockholders’ equity in the period of occurrence and typically results in lower depreciation and depletion expense in future periods. Once incurred, a write-down cannot be reversed at a later date. The ceiling limitation calculation is prepared using the 12-month oil and natural gas average price for the most recent 12 months as of the balance sheet date and as adjusted for basis or location differentials, held constant over the life of the reserves (“net wellhead prices”). If applicable, these net wellhead prices would be further adjusted to include the effects of any fixed price arrangements for the sale of oil and natural gas. Derivative contracts that qualify and are designated as cash flow hedges are included in estimated future cash flows, although the Company historically has not designated any of its derivative contracts as cash flow hedges and has therefore not included its derivative contracts in estimating future cash flows. The future cash outflows associated with future development or abandonment of wells are included in the computation of the discounted present value of future net revenues for purposes of the ceiling limitation calculation. Sales and abandonments of oil and natural gas properties being amortized are accounted for as adjustments to the full cost pool, with no gain or loss recognized, unless the adjustments would significantly alter the relationship between capitalized costs and proved oil, natural gas and NGL reserves. A significant alteration would not ordinarily be expected to occur upon the sale of reserves involving less than 25% of the proved reserve quantities of a cost center. Property, Plant and Equipment, Net. Other capitalized costs, including drilling equipment, natural gas gathering and treating equipment, transportation equipment and other property and equipment are carried at cost. Renewals and improvements are capitalized while repairs and maintenance are expensed. Depreciation of such property and equipment is computed using the straight-line method over the estimated useful lives of the assets, which range from 10 to 39 years for buildings and 3 to 30 years for equipment. When property and equipment components are disposed of, the cost and the related accumulated depreciation are removed and any resulting gain or loss is reflected in the consolidated statements of operations. Realization of the carrying value of property and equipment is reviewed for possible impairment whenever events or changes in circumstances indicate that the carrying value of such asset may not be recoverable. Assets are considered to be impaired if a forecast of undiscounted estimated future net operating cash flows directly related to the asset or asset group including disposal value, if any, is less than the carrying amount of the asset or asset group. If an asset or asset group is considered to be impaired, the impairment loss is measured as the amount by which the carrying amount of the asset or asset group exceeds its fair value. See Note 8 for further discussion of impairments. Capitalized Interest. Interest is capitalized on assets being made ready for use using a weighted average interest rate based on the Company’s borrowings outstanding during that time. During 2015 , 2014 and 2013 , interest of approximately $10.8 million , $14.7 million and $11.7 million , respectively, was capitalized on unproved properties that were not currently being depreciated or depleted and on which exploration activities were in progress. Additionally, interest of $3.3 million , $5.0 million and $4.9 million was capitalized in 2015 , 2014 and 2013 , respectively, on midstream and corporate assets which were under construction. Debt Issuance Costs. The Company amortizes debt issuance costs related to its long-term debt as interest expense over the scheduled maturity period of the related debt. The Company includes unamortized debt issuance costs in other assets in the consolidated balance sheets. Upon retirement of debt, any unamortized costs are written off and included in the determination of the gain or loss on extinguishment of debt. Investments. Investments in marketable equity securities have been designated as available for sale and measured at fair value pursuant to the fair value option which requires unrealized gains and losses be reported in earnings. Asset Retirement Obligations. The Company owns oil and natural gas properties that require expenditures to plug, abandon and remediate wells at the end of their productive lives, in accordance with applicable federal and state laws. Liabilities for these asset retirement obligations are recorded in the period in which the liability is incurred (at the time the wells are drilled or acquired) at the estimated present value at the asset’s inception, with the offsetting increase to property cost. These property costs are depreciated on a unit-of-production basis within the full cost pool. The liability accretes each period until it is settled or the well is sold, at which time the liability is removed. Both the accretion and the depreciation are included in the consolidated statements of operations. The Company determines its asset retirement obligations by calculating the present value of estimated expenses related to the liability. Estimating future asset retirement obligations requires management to make estimates and judgments regarding timing, existence of a liability and what constitutes adequate restoration. Inherent in the present value calculation rates are the timing of settlement and changes in the legal, regulatory, environmental and political environments, which are subject to change. See Note 14 for further discussion of the Company’s asset retirement obligations. Revenue Recognition and Natural Gas Balancing. Sales of oil, natural gas and NGLs are recorded when title of oil, natural gas and NGL production passes to the customer, net of royalties, discounts and allowances, as applicable. Taxes assessed by governmental authorities on oil, natural gas and NGL sales are presented separately from such revenues and included in production tax expense in the consolidated statements of operations. The Company accounts for natural gas production imbalances using the sales method, whereby it recognizes revenue on all natural gas sold to its customers notwithstanding the fact that its ownership may be less than 100% of the natural gas sold. Liabilities are recorded for imbalances greater than the Company’s proportionate share of remaining estimated natural gas reserves. The Company has recorded a liability for natural gas imbalance positions related to natural gas properties with insufficient proved reserves of $1.5 million and $1.4 million at December 31, 2015 and 2014 , respectively. The Company includes the gas imbalance positions in other long-term obligations in the consolidated balance sheets. The Company accounted for its construction contract, discussed in Note 11 , using the completed-contract method, under which contract revenues and costs are recognized when work under the contract is completed or substantially completed and assets have been transferred. In the interim, costs incurred on and billings related to contracts in process are accumulated on the balance sheet. Contract losses are recorded at the time it is determined that a loss will be incurred. Contract gains, if any, are recorded upon substantial completion of the construction project. The Company recognizes revenues and expenses generated from daywork and footage drilling contracts as the services are performed as the Company does not bear the risk of completion of the well. The Company may receive lump-sum fees for the mobilization of equipment and personnel. Mobilization fees received and costs incurred to mobilize a rig from one location to another are recognized at the time mobilization services are performed. In general, natural gas purchased and sold by the midstream business is priced at a published daily or monthly index price. Sales to wholesale customers typically incorporate a premium for managing their transmission and balancing requirements. Midstream services revenues are recognized upon delivery of natural gas to customers and/or when services are rendered, pricing is determined and collectability is reasonably assured. Revenues from third-party midstream services are presented on a gross basis, since the Company acts as a principal by taking ownership of the natural gas purchased and taking responsibility of fulfillment for natural gas volumes sold. Share-Based Compensation. The Company may grant restricted stock awards to members of its Board of Directors (the “Board”) and its employees. Such awards and the related stock-based compensation cost are measured based on the calculated fair value of the award on the grant date. The expense, net of estimated forfeitures, is recognized on a straight-line basis over the employee’s requisite service period, generally the vesting period of the award. The Company grants restricted stock units to members of the Board and its employees. Such awards are settled in cash, shares of Company common stock or a combination of common stock and cash. Restricted stock units vest over a maximum four -year period from the grant date and are valued based upon the Company’s stock price at each period end. To the extent stock-based compensation cost relates to employees directly involved in exploration and development activities, such amounts are capitalized to oil and natural gas properties. Amounts not capitalized are recognized as general and administrative expense, production expense, cost of sales and midstream and marketing expense in the consolidated statements of operations. The related excess tax benefit received upon vesting of restricted stock, if any, is reflected in the consolidated statements of cash flows as a financing activity. The related excess tax expense due upon vesting of restricted stock, if any, is reflected in the consolidated statements of cash flows as an operating activity. Performance Unit Compensation. The Company awards performance units and performance share units, which contain a market-based performance component with cash settlement at the end of the performance period, to certain members of senior management. The Company recognizes a liability and expense for performance unit compensation for the portion earned over the requisite service period in an amount equal to the fair value of the performance units granted. Changes in the fair value of the units for which the service requirement has been met are recognized as compensation expense with a corresponding adjustment to the liability. To the extent performance unit compensation cost relates to those directly involved in exploration and development activities, such amounts are capitalized to oil and natural gas properties. Amounts not capitalized are recognized as general and administrative expense, production expense, cost of sales and midstream and marketing expense in the consolidated statements of operations. Advertising Costs. The Company expenses advertising costs as incurred. Advertising and promotional costs were $0.7 million , $1.3 million , and $5.1 million , respectively, during the years ended December 31, 2015 , 2014 and 2013 . Income Taxes. Deferred income taxes reflect the net tax effects of temporary differences between the amounts of assets and liabilities reported for financial statement purposes and their tax basis. Deferred tax assets are reduced by a valuation allowance if it is deemed more likely than not that some or all of the deferred tax assets will not be realized. The Company has elected an accounting policy in which interest and penalties on income taxes are presented as a component of the income tax provision, rather than as a component of interest expense. Interest and penalties resulting from the underpayment or the late payment of income taxes due to a taxing authority and interest and penalties accrued relating to income tax contingencies, if any, are presented, on a net of tax basis, as a component of the income tax provision. Earnings per Share. Basic earnings per common share is calculated by dividing earnings available to common stockholders by the weighted average number of common shares outstanding during the period. Diluted earnings per common share is calculated by dividing earnings available to common stockholders by the weighted average number of diluted common shares outstanding, which includes the effect of potentially dilutive securities. Potentially dilutive securities for the diluted earnings per share calculation consist of unvested restricted stock awards and restricted share units, using the treasury method, and convertible preferred stock and convertible senior notes, using the if-converted method. Under the treasury method, the amount of unrecognized compensation expense related to unvested stock-based compensation grants is assumed to be used to repurchase shares at the average market price. Under the if-converted method, the Company assumes the conversion of the preferred stock or convertible senior notes to common stock and determines if it is more dilutive than including the preferred stock dividends or expense associated with the convertible senior notes, respectively, in the computation of income available to common stockholders. When a loss exists, all potentially dilutive securities are anti-dilutive and are therefore excluded from the computation of diluted earnings per share. See Note 20 for the Company’s earnings per share calculation. Commitments and Contingencies. Liabilities for loss contingencies arising from claims, assessments, litigation or other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated. Environmental expenditures are expensed or capitalized, as appropriate, depending on future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed. Liabilities related to future costs are recorded on an undiscounted basis when environmental assessments and/or remediation activities are probable and costs can be reasonably estimated. See Note 15 for discussion of the Company’s commitments and contingencies. Concentration of Risk. All of the Company’s commodity derivative transactions have been carried out in the over-the-counter market. The entry into derivative transactions in the over-the-counter market involves the risk that the counterparties may be unable to meet the financial terms of the transactions. The counterparties for all of the Company’s commodity derivative transactions have an “investment grade” credit rating. The Company monitors on an ongoing basis the credit ratings of its commodity derivative counterparties and considers its counterparties’ credit default risk ratings in determining the fair value of its commodity derivative contracts. The Company’s commodity derivative contracts are with multiple counterparties to minimize its exposure to any individual counterparty. A default by the Company under its senior credit facility constitutes a default under its commodity derivative contracts with counterparties that are lenders under the senior credit facility. The Company does not require collateral or other security from counterparties to support commodity derivative

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2015
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Supplemental disclosures to the consolidated statements of cash flows are presented below: Years Ended December 31, 2015 2014 2013 (In thousands) Supplemental Disclosure of Cash Flow Information Cash paid for interest, net of amounts capitalized $ (296,386 ) $ (235,793 ) $ (274,850 ) Cash (paid) received for income taxes $ (88 ) $ 1,928 $ (4,610 ) Supplemental Disclosure of Noncash Investing and Financing Activities Deposit on pending sale $ — $ — $ (255,000 ) Change in accrued capital expenditures $ 177,586 $ (55,557 ) $ 72,848 Equity issued for debt $ (63,299 ) $ — $ — Preferred stock dividends paid in common stock $ (16,188 ) $ — $ — Long-term debt issued, including derivative and net of discount, for asset acquisition and termination of gathering agreement $ (50,310 ) $ — $ —

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2015
Acquisitions And Dispositions [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures 2015 Acquisitions Acquisition of Piñon Gathering Company, LLC . In October 2015, the Company acquired all of the assets of and terminated a gathering agreement with Piñon Gathering Company, LLC (“PGC’) for $48.0 million in cash and $78.0 million principal amount of newly issued 8.75% Senior Secured Notes due 2020 (“PGC Senior Secured Notes”). PGC owns approximately 370 miles of gathering lines supporting the natural gas production from the Company's Piñon field in the West Texas Overthrust (“WTO”). The transaction resulted in the termination of the Company’s gas gathering agreement with PGC under which it was required to compensate PGC for any throughput shortfalls below a required minimum volume. The fair value of the consideration paid by the Company, including discount attributable to the PGC Senior Secured Notes, was approximately $98.3 million and was allocated on a fair value basis between the assets acquired (approximately $47.3 million ) and a loss on the termination of the gathering contract (approximately $51.0 million ). See Note 4 for further discussion of the gathering agreement with PGC. Acquisition of Rockies Properties. In December 2015, the Company acquired approximately 135,000 net acres in the North Park Basin in the Rockies, in Jackson County, Colorado. The Company paid approximately $191.1 million in cash, including post-closing adjustments, and received $3.1 million from the seller for overriding royalty interests. Also included in the acquisition were working interests in 16 wells previously drilled on the acreage. 2014 Divestiture Sale of Gulf of Mexico and Gulf Coast Properties. On February 25, 2014 , the Company sold subsidiaries that owned the Company’s Gulf of Mexico and Gulf Coast oil and natural gas properties (the “Gulf Properties”) for approximately $702.6 million , net of working capital adjustments and post-closing adjustments, and the buyer’s assumption of approximately $366.0 million of related asset retirement obligations to Fieldwood Energy LLC (“Fieldwood”). This transaction did not result in a significant alteration of the relationship between the Company’s capitalized costs and proved reserves and, accordingly, the Company recorded the proceeds as a reduction of its full cost pool with no gain or loss on the sale. See Note 21 for discussion of Fieldwood’s related party affiliation with the Company. In accordance with the terms of the sale, the Company agreed to guarantee on behalf of Fieldwood certain plugging and abandonment obligations associated with the Gulf Properties for a period of up to one year from the date of closing. The Company recorded a liability equal to the fair value of these guarantees, or $9.4 million , at the time the transaction closed. As of December 31, 2014, the fair value of the guarantees was approximately $5.1 million . See Note 5 for additional discussion of the determination of the guarantee’s fair value. The guarantee did not include a limit on the potential future payments for which the Company could be obligated; however, Fieldwood agreed to indemnify the Company for any costs it incurred as a result of the guarantee and to use its best efforts to pay any amounts sought from the Company by the Bureau of Ocean Energy Management (“BOEM”) that arose prior to the expiration of the guarantee. The Company did not incur any costs as a result of this guarantee and was released from the obligation during the third quarter of 2015. Additionally, Fieldwood maintained, for a period of up to one year from the closing date, restricted deposits held in escrow for plugging and abandonment obligations associated with the Gulf Properties. In the first quarter of 2015, the Company received its share of such deposits, net of any amounts payable to Fieldwood, or $12.0 million , in accordance with the terms of the sale. The following table presents revenues and expenses, including direct operating expenses, depletion, accretion of asset retirement obligations and general and administrative expenses, for the Gulf Properties included in the accompanying consolidated statements of operations for the years ended December 31, 2014 and 2013 (in thousands): Year Ended December 31, 2014(1) 2013 Revenues $ 90,920 $ 627,236 Expenses $ 63,674 $ 491,991 ____________________ (1) Includes revenues and expenses through February 25, 2014 , the date of the sale. 2013 Divestiture Sale of Permian Properties. On February 26, 2013, the Company sold its oil and natural gas properties in the Permian Basin area of west Texas, excluding the assets associated with the SandRidge Permian Trust area of mutual interest (the “Permian Properties”) for $2.6 billion , including certain post-closing adjustments that were finalized in the third quarter of 2013. This transaction resulted in a significant alteration of the relationship between the Company’s capitalized costs and proved reserves and, accordingly, the Company recorded a $398.9 million loss on the sale. The loss is included in loss on sale of assets in the accompanying consolidated statement of operations for the year ended December 31, 2013. The loss was calculated based on a comparison of proceeds received and the asset retirement obligations attributable to the Permian Properties that were assumed by the buyer to the sum of (i) an allocation of the historical net book value of the Company’s proved oil and natural gas properties attributable to the Permian Properties, (ii) the historical cost of unproved acreage sold and (iii) costs incurred by the Company to sell these properties. The allocated net book value attributable to the Permian Properties was calculated based on the relative fair value of the Permian Properties and the remaining proved oil and natural gas properties retained by the Company as of the date of sale. A portion of the loss totaling $71.7 million was allocated to noncontrolling interests and is reflected in net income attributable to noncontrolling interest in the accompanying consolidated statement of operations for the year ended December 31, 2013. The following table presents revenues and direct operating expenses of the Permian Properties included in the accompanying consolidated statement of operations for the year ended December 31, 2013 (in thousands): Year Ended December 31, 2013(1) Revenues $ 68,027 Direct operating expenses $ 17,453 ____________________ (1) Includes revenues and direct operating expenses through February 26, 2013, the date of sale.

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Variable Interest Entities	Variable Interest Entities The Company’s significant associated VIEs, including those for which the Company has determined it is the primary beneficiary and those for which it has determined it is not, are described below. Royalty Trusts SandRidge owns beneficial interests in the SandRidge Mississippian Trust I (the “Mississippian Trust I”), the SandRidge Permian Trust (the “Permian Trust”) and SandRidge Mississippian Trust II (the “Mississippian Trust II”) (each individually, a “Royalty Trust” and collectively, the “Royalty Trusts”). The Royalty Trusts are considered VIEs due to the lack of voting or similar decision-making rights of the Royalty Trusts’ equity holders regarding activities that have a significant effect on the economic success of the Royalty Trusts. The Company has determined it is the primary beneficiary of the Royalty Trusts as it has (a) the power to direct the activities that most significantly impact the economic performance of the Royalty Trusts through (i) its participation in the creation and structure of the Royalty Trusts, (ii) the manner in which it fulfilled its drilling obligations to the Royalty Trusts as discussed below and (iii) its operation of a majority of the oil and natural gas properties that are subject to the conveyed royalty interests and marketing of the associated production, and (b) the obligation to absorb losses and right to receive residual returns, through its variable interests in the Royalty Trusts, including ownership of common and/or subordinated units, that could potentially be significant to the Royalty Trusts. As a result, the Company consolidates the activities of the Royalty Trusts. The common units of the Royalty Trusts owned by third parties are reflected as noncontrolling interest in the consolidated financial statements. Common and subordinated units outstanding as of December 31, 2015 and 2014 for each Royalty Trust are as follows: Mississippian Trust I (1) Permian Trust Mississippian Trust II Total outstanding common units 28,000,000 39,375,000 37,293,750 Total outstanding subordinated units(2) — 13,125,000 12,431,250 ____________________ (1) The Mississippian Trust I’s previously outstanding subordinated units, all of which were held by SandRidge, converted to common units on July 1, 2014. (2) All outstanding subordinated units are owned by SandRidge. The Company’s beneficial interest in the Royalty Trusts at December 31, 2015 and 2014 were as follows: Mississippian Trust I 26.9 % Permian Trust 25.0 % Mississippian Trust II 37.6 % Royalty Interests. The Royalty Trusts own royalty interests in oil and natural gas wells that were either (i) conveyed to the Royalty Trusts by SandRidge concurrent with the closing of each Royalty Trust’s initial public offering or (ii) drilled within a defined area of mutual interest during a specified period of time as discussed further below. Pursuant to the agreements governing the Royalty Trusts, the Mississippian Trust I will terminate in 2030 and the Permian Trust and Mississippian Trust II will terminate in 2031. Upon termination, 50% of the royalty interests of each Royalty Trust will automatically revert to the Company, and the remaining 50% will be sold, with the proceeds distributed to the Royalty Trust unitholders. Drilling Obligations. The Company and one of its wholly owned subsidiaries entered into a development agreement with each Royalty Trust upon conveyance of the royalty interests by the Company that obligated the Company to drill, or cause to be drilled, a specified number of wells which are also subject to the royalty interests within respective areas of mutual interest by a specified date. One of the Company’s wholly owned subsidiaries also granted to each Royalty Trust a lien on the Company’s interests in the properties where the development wells were to be drilled in order to secure the estimated amount of drilling costs for the Royalty Trust’s interests in the wells. The total amount that may be recovered by each Royalty Trust under its respective lien was proportionately reduced as the Company has drilled and completed the associated development wells. The Company fulfilled its drilling obligation to the Mississippian Trust I in the second quarter of 2013, to the Permian Trust in the fourth quarter of 2014 and to the Mississippian Trust II in the first quarter of 2015 and the related liens were automatically released. Distributions. The Royalty Trusts make quarterly cash distributions to unitholders based on calculated distributable income. While outstanding, subordinated units, which constitute 25% of each Royalty Trust’s total outstanding units during the subordination period as described below, are entitled to receive pro rata distributions from the Royalty Trusts each quarter if and to the extent there is sufficient cash to provide a cash distribution on the common units that is no less than the applicable quarterly subordination threshold. If there is not sufficient cash to fund such a distribution on all common units, the distribution made with respect to the subordinated units is reduced or eliminated for such quarter in order to make a distribution, to the extent possible, of up to the subordination threshold amount on all common units, including common units held by the Company. As holder of the subordinated units, SandRidge is entitled to receive incentive distributions equal to 50% of the amount by which the cash available for distribution on all of the Royalty Trust units exceeds the applicable quarterly incentive threshold during the subordination period. Quarterly distributions declared and paid by the Royalty Trusts during the years ended December 31, 2015 , 2014 and 2013 as follows (in thousands): Year Ended December 31, 2015(1) 2014(2) 2013(3) Total distributions $ 158,632 $ 234,326 $ 299,674 Distributions to third-party unitholders $ 138,305 $ 193,807 $ 206,470 ____________________ (1) Subordination thresholds were not met for the Permian Trust and Mississippian Trust II’s distributions for the year ended December 31, 2015 , resulting in reduced distributions to the Company on its subordinated units for this period. (2) Subordination thresholds were not met for the Mississippian Trust I’s first or second quarter 2014 distributions, the Permian Trust’s second, third or fourth quarter 2014 distributions or for the Mississippian Trust II’s distributions for the year ended December 31, 2014, resulting in reduced distributions to the Company on its subordinated units for these periods. (3) Subordination thresholds were not met for the Mississippian Trust I’s second, third or fourth quarter 2013 distributions, the Permian Trust’s second quarter 2013 distribution or for the Mississippian Trust II’s fourth quarter 2013 distribution, resulting in reduced distributions to the Company on its subordinated units for these periods. See Note 22 for discussion of the Royalty Trusts’ distributions announced in January 2016. Following the end of the fourth full calendar quarter subsequent to the Company’s satisfaction of its drilling obligation (the “subordination period”), the subordinated units of each Royalty Trust automatically convert into common units on a one-for-one basis and the Company’s right to receive incentive distributions terminates. In the third quarter of 2014, the Mississippian Trust I’s subordinated units, all of which were held by SandRidge, converted to common units. Beginning with the distribution made in November 2014, all of the Mississippian Trust I’s common units share equally in its distributions. Similarly, as a result of the Company’s fulfillment of its drilling obligations to the Permian Trust and the Mississippian Trust II, the subordinated units of each of these Royalty Trusts will convert to common units on January 1, 2016 and April 1, 2016, respectively, and distributions made in respect of periods thereafter will be shared equally by the Royalty Trusts’ common units. The Company will continue to consolidate the activities of the Royalty Trusts as primary beneficiary subsequent to these conversions due to the Company’s original participation in the design of the Royalty Trusts and continued (a) power to direct the activities that most significantly impact the economic performance of the Royalty Trusts and (b) obligation to absorb losses and right to receive residual returns through its variable interests in the Royalty Trusts, including ownership of common units, that could potentially be significant to the Royalty Trusts. Loan Commitment. Pursuant to the agreements governing the Royalty Trusts, the Company has committed to loan funds to each Royalty Trust on an unsecured basis, with terms substantially the same as would be obtained in an arm’s length transaction between the Company and an unaffiliated party, if at any time the Royalty Trust’s cash is not sufficient to pay ordinary course administrative expenses as they become due. Any funds loaned may not be used to satisfy indebtedness of the Royalty Trust or to make distributions. There were no amounts outstanding under the loan commitments at December 31, 2015 or 2014 . Administrative Services. The Company is party to an administrative services agreement with each Royalty Trust, pursuant to which the Company provides certain administrative services to the Royalty Trust, which included hedge management services to the Permian Trust and the Mississippian Trust II during the terms of the respective derivative agreements. Derivatives Agreements. The Company had a derivatives agreement with each Royalty Trust, pursuant to which the Company provided to the Royalty Trust the economic effects of certain of the Company’s derivative contracts covering production through December 31, 2015 for the Mississippian Trust I and the Mississippian Trust II and through March 31, 2015 for the Permian Trust. These agreements expired upon expiration of the underlying derivative contracts. See Note 13 for further discussion of the derivatives agreement between the Company and each Royalty Trust. Assets and Liabilities. Each Royalty Trust’s assets can be used to settle only that Royalty Trust’s obligations and not other obligations of the Company or another Royalty Trust. The Royalty Trusts’ creditors have no contractual recourse to the general credit of the Company. Although the Royalty Trusts are included in the Company’s consolidated financial statements, the Company’s legal interest in the Royalty Trusts’ assets is limited to its ownership of the Royalty Trusts’ units. At December 31, 2015 and 2014 , $510.2 million and $1.3 billion , respectively, of noncontrolling interest in the accompanying consolidated balance sheets were attributable to the Royalty Trusts. The Royalty Trusts’ assets and liabilities, after considering the effects of intercompany eliminations, included in the accompanying consolidated balance sheets at December 31, 2015 and 2014 consisted of the following (in thousands): December 31, 2015 2014 Cash and cash equivalents(1) $ 7,824 $ 9,387 Accounts receivable 4,457 17,660 Derivative contracts — 6,589 Total current assets 12,281 33,636 Investment in royalty interests(2) 1,325,942 1,325,942 Less: accumulated depletion and impairment(3) (1,248,957 ) (284,094 ) 76,985 1,041,848 Total assets $ 89,266 $ 1,075,484 Accounts payable and accrued expenses $ 1,060 $ 2,852 Total liabilities $ 1,060 $ 2,852 ____________________ (1) Includes $3.0 million held by the trustee at December 31, 2015 and 2014 as reserves for future general and administrative expenses. (2) Investment in royalty interests is included in oil and natural gas properties in the accompanying consolidated balance sheets. (3) Includes cumulative full cost ceiling limitation impairment of $976.2 million and $42.3 million at December 31, 2015 and 2014 , respectively. See Note 15 for discussion of the Company’s legal proceedings to which the Mississippian Trust I and Mississippian Trust II are also parties. Sales of Common Units. During the years ended December 31, 2014 and 2013 , the Company sold Royalty Trust common units it owned in transactions exempt from registration pursuant to Rule 144 under the Securities Act for proceeds of approximately $22.1 million and $29.0 million , respectively. The unit sales were accounted for as equity transactions with no gain or loss recognized. The Company continued to be the primary beneficiary of the Royalty Trusts after consideration of these transactions and continues to consolidate the activities of the Royalty Trusts. Grey Ranch Plant, L.P. Primarily engaged in treating and transportation of natural gas, Grey Ranch Plant, L.P. (“GRLP”) was a limited partnership that operated the Company’s Grey Ranch plant (the “Plant”) located in Pecos County, Texas. As of December 31, 2013, the Company owned a 50% interest in GRLP, which represented a variable interest. Income or loss of GRLP was allocated to the partners based on ownership percentage and any operating or cash shortfalls required contributions from the partners. GRLP was considered a VIE because certain equity holders lacked the ability to participate in decisions impacting GRLP. Agreements related to the ownership and operation of GRLP provided for GRLP to pay management fees to the Company to operate the Plant and lease payments for the Plant. Under the operating agreements, lease payments were reduced if throughput volumes were below those expected. The Company determined that it was the primary beneficiary of GRLP as it had both (i) the power, as operator of the Plant, to direct the activities of GRLP that most significantly impact its economic performance and (ii) the obligation to absorb losses, as a result of the operating and gathering agreements, that could potentially be significant to GRLP and, therefore, consolidated the activity of GRLP in its consolidated financial statements. The 50% ownership interest not held by the Company as of December 31, 2013 is presented as noncontrolling interest in the consolidated financial statements. In the first quarter of 2014, one of the Company’s wholly owned subsidiaries acquired from a third party the remaining 50% ownership interest of GRLP. Because the Company was the primary beneficiary and consolidated GRLP, the acquisition of additional ownership interest was recorded as an equity transaction with no gain or loss recognized. Additionally, as a wholly owned subsidiary of the Company, GRLP is no longer considered a VIE for reporting purposes. Grey Ranch Plant Genpar, LLC As of December 31, 2013, the Company owned a 50% interest in Grey Ranch Plant Genpar, LLC (“Genpar”), the managing partner and 1% owner of GRLP. The Company served as Genpar’s administrative manager. Genpar’s ownership interest in GRLP was its only asset. As managing partner of GRLP, Genpar had the sole right to manage, control and conduct the business of GRLP. However, Genpar was restricted from making certain major decisions, including the decision to remove the Company as operator of the Plant. The rights afforded the Company under the Plant operating agreement and the restrictions on Genpar limited Genpar’s ability to make decisions on behalf of GRLP. Therefore, Genpar was considered a VIE. Although both the Company and Genpar’s other equity owner shared equally in Genpar’s economic losses and benefits and also had agreements that may be considered variable interests, the Company determined it was the primary beneficiary of Genpar due to (i) its ability, as administrative manager and operator of the Plant, to direct the activities of Genpar that most significantly impacted its economic performance and (ii) its obligation or right, as operator of the Plant, to absorb the losses of or receive benefits from Genpar that could potentially have been significant to Genpar. As the primary beneficiary, the Company consolidated Genpar’s activity. However, its sole asset, the investment in GRLP, was eliminated in consolidation. Genpar had no liabilities. In the first quarter of 2014, one of the Company’s wholly owned subsidiaries acquired from a third party the remaining 50% ownership interest of Genpar. Because the Company was the primary beneficiary and consolidated Genpar, the acquisition of additional ownership interest was recorded as an equity transaction with no gain or loss recognized. Additionally, as a wholly owned subsidiary of the Company, Genpar is no longer considered a VIE for reporting purposes. Piñon Gathering Company, LLC PGC’s assets consist of approximately 370 miles of gathering lines that support the Company’s production in the Piñon field in West Texas. The Company acquired PGC in October 2015, and upon acquisition, terminated a gas gathering and operations and maintenance agreement with PGC, which required the Company to compensate PGC for any throughput shortfalls below a required minimum volume through June 30, 2029. By guaranteeing a minimum throughput, the Company absorbed the risk that lower than projected volumes would be gathered by the PGC’s gathering system. Therefore, prior to its acquisition, PGC was a VIE. Other than as required under the gas gathering and operations and maintenance agreements, the Company did not provide any support to PGC. While the Company operated the assets of PGC as directed under the operations and management agreement, the member and managers of PGC had the authority to directly control PGC and make substantive decisions regarding PGC’s activities including terminating the Company as operator without cause. As the Company did not have the ability to control the activities of PGC that most significantly impact PGC’s economic performance, the Company was not the primary beneficiary of PGC and, therefore, and did not consolidate the results of PGC’s activities into the Company’s financial statements prior to its acquisition. As a wholly owned subsidiary, PGC is no longer considered a VIE for reporting purposes. Amounts due from and due to PGC as of December 31, 2014 included in the accompanying consolidated balance sheet are as follows (in thousands): December 31, 2014 Accounts receivable due from PGC $ 1,141 Accounts payable due to PGC $ 4,163

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The Company measures and reports certain assets and liabilities on a fair value basis and has classified and disclosed its fair value measurements using the following levels of the fair value hierarchy: Level 1 Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. Level 2 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. Level 3 Measurement based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable for objective sources ( i.e., supported by little or no market activity). Assets and liabilities that are measured at fair value are classified based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The determination of the fair values, stated below, considers the market for the Company’s financial assets and liabilities, the associated credit risk and other factors. The Company considers active markets as those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis. The Company has assets and liabilities classified in each level of the hierarchy as of December 31, 2015 and 2014 , as described below. Level 1 Fair Value Measurements Investments. The fair value of investments, consisting of assets attributable to the Company’s non-qualified deferred compensation plan, is based on quoted market prices. Investments are included in other assets in the accompanying consolidated balance sheets. Level 2 Fair Value Measurements Commodity Derivative Contracts. The fair values of the Company’s oil and natural gas fixed price swaps and oil and natural gas collars are based upon inputs that are either readily available in the public market, such as oil and natural gas futures prices, volatility factors and discount rates, or can be corroborated from active markets. Fair value is determined through the use of a discounted cash flow model or option pricing model using the applicable inputs, discussed above. The Company applies a weighted average credit default risk rating factor for its counterparties or gives effect to its credit default risk rating, as applicable, in determining the fair value of these derivative contracts. Credit default risk ratings are based on current published credit default swap rates. Mandatory Prepayment Feature - PGC Senior Secured Notes. In conjunction with the acquisition of and termination of a gathering agreement with PGC in October 2015, the Company issued the PGC Senior Secured Notes with a $78.0 million principal value. These notes bear payment terms identical to and are secured by the same assets as the 8.75% Senior Secured Notes due 2020 issued by the Company in June 2015 as discussed in Note 12 . The 8.75% Senior Secured Notes due 2020 issued in June 2015 and PGC Senior Secured Notes (collectively, “Senior Secured Notes”) will mature on June 1, 2020; provided, however, that if on October 15, 2019, the aggregate outstanding principal amount of the Company’s unsecured 8.75% Senior Notes due 2020 exceeds $100.0 million , the Senior Secured Notes will mature on October 16, 2019. The issuance of the PGC Senior Secured Notes at a substantial discount, as discussed in Note 12 and Note 13 , resulted in the treatment of the mandatory prepayment feature contained in those notes as an embedded derivative that meets the criteria to be bifurcated from its host contract, the PGC Senior Secured Notes, and accounted for separately from those notes. The mandatory prepayment feature contained in the PGC Senior Secured Notes is recorded at fair value each reporting period based upon values determined through the use of discounted cash flow models of the PGC Senior Secured Notes both (i) with the mandatory prepayment feature and (ii) excluding the mandatory prepayment feature. Level 3 Fair Value Measurements Commodity Derivative Contracts. The fair value of the Company’s natural gas basis swaps are based upon quotes obtained from counterparties to the derivative contracts. These values were reviewed internally for reasonableness through the use of a discounted cash flow model using non-exchange traded regional pricing information. Additionally, the Company applied a weighted average credit default risk rating factor for its counterparties or gave effect to its credit risk, as applicable, in determining the fair value of these commodity derivative contracts. The significant unobservable input used in the fair value measurement of the Company’s natural gas basis swaps is the estimate of future natural gas basis differentials. Significant increases (decreases) in natural gas basis differentials could result in a significantly higher (lower) fair value measurement. The significant unobservable inputs and the range and weighted average of these inputs used in the fair value measurements of the Company’s natural gas basis swaps at December 31, 2015 and 2014 are included in the table below. Unobservable Input Range Weighted Average Fair Value (Price per Mcf) (In thousands) December 31, 2015 Natural gas basis differential forward curve $ (0.06 ) – $ (0.28 ) $ (0.22 ) $ (1,748 ) December 31, 2014 Natural gas basis differential forward curve $ (0.03 ) – $ (0.38 ) $ (0.29 ) $ 350 Long-Term Debt Holder Conversion Feature . In August 2015, the Company issued its Convertible Senior Unsecured Notes, each of which contain a conversion option whereby the Convertible Senior Unsecured Notes holders have the option to convert the notes into shares of Company common stock. Further, with respect to any such conversions prior to the second anniversary of the issuance of the Convertible Senior Unsecured Notes, in addition to the shares deliverable upon conversion, holders are entitled to receive an early conversion payment. These conversion features have been identified as embedded derivatives that meet the criteria to be bifurcated from their host contracts, the Convertible Senior Unsecured Notes, and accounted for separately from those notes. The holder conversion features are recorded at fair value each reporting period. The fair values of the holder conversion features were determined using a binomial lattice model based on certain assumptions including (i) the Company’s stock price, (ii) risk-free rate, (iii) recovery rate, (iv) hazard rate and (v) expected volatility. The significant unobservable input used in the fair value measurement of the conversion features is the hazard rate, an estimate of default probability. Significant increases (decreases) in the hazard rate could result in significantly (lower) higher fair value measurement. The significant unobservable inputs and range and weighted average of these inputs used in the fair value measurement of the conversion features at December 31, 2015 are included in the table below. Unobservable Input Range Weighted Average Fair Value (In thousands) December 31, 2015 Long-term debt conversion feature hazard rate 114.0 % – 135.2 % 119.2 % $ 29,355 See further discussion of the Convertible Senior Unsecured Notes at Note 12 . Guarantees. As discussed in Note 3 , the Company guaranteed on Fieldwood’s behalf certain plugging and abandonment obligations associated with the Gulf Properties from the date of closing until the Company was released from the guarantee in the third quarter of 2015. The fair value of this guarantee was based on the present value of estimated future payments for plugging and abandonment obligations associated with the Gulf Properties, adjusted for the cumulative probability of Fieldwood’s default prior to the Company’s release by the BOEM from its obligation under the guarantee ( 3.71% at December 31, 2014). The discount and probability of default rates were based upon inputs that are readily available in the public market, such as historical option adjusted spreads of the Company’s senior notes, which are publicly traded, and historical default rates of publicly traded companies with credit ratings similar to Fieldwood. The significant unobservable input used in the fair value measurement of the guarantees was the estimate of future payments for plugging and abandonment of approximately $372.0 million , which was developed based upon third-party quotes and then-current actual costs. Significant increases (decreases) in the estimate of these payments could have resulted in a significantly higher (lower) fair value measurement. Fair Value - Recurring Measurement Basis The following tables summarize the Company’s assets and liabilities measured at fair value on a recurring basis by the fair value hierarchy (in thousands): December 31, 2015 Fair Value Measurements Netting(1) Assets/Liabilities at Fair Value Level 1 Level 2 Level 3 Assets Commodity derivative contracts $ — $ 85,524 $ — $ (1,175 ) $ 84,349 Investments 10,106 — — — 10,106 $ 10,106 $ 85,524 $ — $ (1,175 ) $ 94,455 Liabilities Commodity derivative contracts $ — $ — $ 1,748 $ (1,175 ) $ 573 Long-term debt holder conversion feature — — 29,355 — 29,355 Mandatory prepayment feature - PGC Senior Secured Notes — 2,941 — — 2,941 $ — $ 2,941 $ 31,103 $ (1,175 ) $ 32,869 December 31, 2014 Fair Value Measurements Netting(1) Assets/Liabilities at Fair Value Level 1 Level 2 Level 3 Assets Commodity derivative contracts $ — $ 338,067 $ 350 $ — $ 338,417 Investments 11,106 — — — 11,106 $ 11,106 $ 338,067 $ 350 $ — $ 349,523 Liabilities Guarantee $ — $ — $ 5,104 $ — $ 5,104 $ — $ — $ 5,104 $ — $ 5,104 ____________________ (1) Represents the impact of netting assets and liabilities with counterparties with which the right of offset exists. Level 3 - Commodity Derivative Contracts. The table below sets forth a reconciliation of the Company’s Level 3 fair value measurements for commodity derivative contracts during the years ended December 31, 2015 , 2014 and 2013 (in thousands): Level 3 Fair Value Measurements - Commodity Derivative Contracts 2015 2014 2013 Beginning balance $ 350 $ — $ (512 ) Loss on commodity derivative contracts (350 ) — (133 ) Purchases (1,748 ) 350 — Settlements paid — — 645 Level 3 commodity derivative contracts at December 31 $ (1,748 ) $ 350 $ — Losses due to changes in fair value of the Company’s Level 3 commodity derivative contracts have been included in (gain) loss on derivative contracts in the accompanying consolidated statements of operations. There were no outstanding Level 3 commodity derivative contracts at December 31, 2013. See Note 13 for further discussion of the Company’s derivative contracts. Level 3 - Long-Term Debt Holder Conversion Feature. The table below sets forth a reconciliation of the Company’s Level 3 fair value measurements for long-term debt holder conversion features during the year ended December 31, 2015 (in thousands): Level 3 Fair Value Measurements - Long-Term Debt Holder Conversion Feature Beginning balance $ — Issuances 31,200 Gain on derivative holder conversion feature 10,198 Conversions (12,043 ) Ending balance $ 29,355 The fair value of the conversion features are determined quarterly with changes in fair value recorded as interest expense. Level 3 - Guarantee. The table below sets forth a reconciliation of the Company’s Level 3 fair value measurements for guarantees during the years ended December 31, 2015 and 2014 (in thousands): Level 3 Fair Value Measurements - Guarantee 2015 2014 Beginning balance $ 5,104 $ — Issuances — 9,446 Loss on guarantee — (4,342 ) Settlements (5,104 ) — Ending balance $ — $ 5,104 While in effect, the fair value of the guarantee was determined quarterly with changes in fair value recorded as an adjustment to the full cost pool. See Note 3 for discussion of the sale of the Gulf Properties. The fair value of the guarantees as of December 31, 2014 is included in other current liabilities in the accompanying consolidated balance sheet. Transfers. The Company recognizes transfers between fair value hierarchy levels as of the end of the reporting period in which the event or change in circumstances causing the transfer occurred. During the years ended December 31, 2015 , 2014 and 2013 , the Company did not have any transfers between Level 1, Level 2 or Level 3 fair value measurements. Fair Value of Financial Instruments - Long-Term Debt The Company measures the fair value of its Senior Secured Notes, its 8.75% Senior Notes due 2020, 7.5% Senior Notes due 2021, 8.125% Senior Notes due 2022, and 7.5% Senior Notes due 2023 (collectively, “Senior Unsecured Notes”) and the Convertible Senior Unsecured Notes using pricing that is readily available in the public market. The Company classifies these inputs as Level 2 in the fair value hierarchy. The estimated fair values and carrying values of the Company’s senior notes at December 31, 2015 and 2014 were as follows (in thousands): December 31, 2015 December 31, 2014 Fair Value Carrying Value Fair Value Carrying Value 8.75% Senior Secured Notes due 2020(1) $ 403,098 $ 1,301,098 $ — $ — Senior Unsecured Notes 8.75% Senior Notes due 2020(2) $ 39,740 $ 392,666 $ 303,750 $ 445,402 7.5% Senior Notes due 2021(3) $ 79,812 $ 759,711 $ 752,000 $ 1,178,486 8.125% Senior Notes due 2022 $ 57,749 $ 527,737 $ 472,500 $ 750,000 7.5% Senior Notes due 2023(4) $ 58,799 $ 541,572 $ 519,750 $ 821,548 Convertible Senior Unsecured Notes 8.125% Convertible Senior Notes due 2022(5) $ 44,199 $ 82,294 $ — $ — 7.5% Convertible Senior Notes due 2023(6) $ 15,125 $ 26,428 $ — $ — ___________________ (1) Carrying value includes mandatory prepayment feature liabilities with fair value of $2,941 and is net of $29,842 discount at December 31, 2015 . (2) Carrying value is net of $3,269 and $4,598 discount at December 31, 2015 and 2014 , respectively. (3) Carrying value includes a premium of $1,944 and $3,486 at December 31, 2015 and 2014 , respectively. (4) Carrying value is net of $1,989 and $3,452 discount at December 31, 2015 and 2014 , respectively. (5) Carrying value includes holder conversion feature liabilities with fair value of $21,874 and is net of $180,751 discount at December 31, 2015 . (6) Carrying value includes holder conversion feature liabilities with fair value of $7,481 and is net of $59,549 discount at December 31, 2015 .

Accounts Receivable

Accounts Receivable	12 Months Ended
	Dec. 31, 2015
Receivables [Abstract]
Accounts Receivable	Accounts Receivable A summary of accounts receivable is as follows (in thousands): December 31, 2015 2014 Oil, natural gas and NGL sales $ 61,140 $ 139,848 Joint interest billing 60,403 170,937 Oil and natural gas services 2,417 21,436 Other 8,274 4,939 132,234 337,160 Less: allowance for doubtful accounts (4,847 ) (7,083 ) Total accounts receivable, net $ 127,387 $ 330,077 The following table presents the balance and activity in the allowance for doubtful accounts for the years ended December 31, 2015 , 2014 and 2013 (in thousands): Year Ended December 31, 2015 2014 2013 Beginning balance $ 7,083 $ 11,061 $ 5,635 Additions charged to costs and expenses(1) 1,320 818 5,497 Deductions(2) (3,556 ) (4,796 ) (71 ) Ending balance $ 4,847 $ 7,083 $ 11,061 ____________________ (1) Includes $2.7 million of allowance for receivables deemed uncollectible at December 31, 2013, primarily due to the bankruptcy status of customers. (2) Deductions represent write-off of receivables and collections of amounts for which an allowance had previously been established. Deductions in 2015 are primarily due to the write-off of receivables in conjunction with a lawsuit settlement, and deductions in 2014 are related to the sale of the Gulf Properties.

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment consists of the following (in thousands): December 31, 2015 2014 Oil and natural gas properties Proved(1) $ 12,529,681 $ 11,707,147 Unproved 363,149 290,596 Total oil and natural gas properties 12,892,830 11,997,743 Less accumulated depreciation, depletion and impairment (11,149,888 ) (6,359,149 ) Net oil and natural gas properties capitalized costs 1,742,942 5,638,594 Land 14,260 16,300 Non-oil and natural gas equipment(2) 373,687 602,392 Buildings and structures(3) 227,673 263,191 Total 615,620 881,883 Less accumulated depreciation and amortization (123,860 ) (305,420 ) Other property, plant and equipment, net 491,760 576,463 Total property, plant and equipment, net $ 2,234,702 $ 6,215,057 ____________________ (1) Includes cumulative capitalized interest of approximately $48.9 million and $38.1 million at December 31, 2015 and 2014 , respectively. (2) Includes cumulative capitalized interest of approximately $4.3 million at both December 31, 2015 and 2014 . (3) Includes cumulative capitalized interest of approximately $20.4 million and $17.1 million at December 31, 2015 and 2014 , respectively. Accumulated depreciation, depletion and impairment for oil and natural gas properties includes cumulative full cost ceiling limitation impairment of $8.2 billion and $3.7 billion at December 31, 2015 and 2014 , respectively. During the years ended December 31, 2015 and 2014 , the Company reduced the net carrying value of its oil and natural gas properties by $4.5 billion and $164.8 million , respectively, as a result of its quarterly full cost ceiling analyses. There was no full cost ceiling impairment during the year ended December 31, 2013. See Note 8 for discussion of impairment of other property, plant and equipment. The average rates used for depreciation and depletion of oil and natural gas properties were $10.67 per Boe in 2015 , $15.00 per Boe in 2014 and $16.81 per Boe in 2013 . During the second and fourth quarters of 2015, the Company classified drilling and oilfield services assets having net book values of approximately $20.0 million and $16.0 million , respectively, as held for sale as a result of the Company’s decisions to discontinue substantially all drilling and oilfield services operations first in the Permian region and then companywide. The Company disposed of certain drilling and oilfield services assets held for sale during the third quarter of 2015 and recorded a loss on sale of assets of $3.5 million for the year ended December 31, 2015 . The Company expects to dispose of the remaining assets classified as held for sale at December 31, 2015 prior to the fourth quarter of 2016. Drilling Carry Commitments During the years ended December 31, 2014 and 2013, the Company was party to agreements with two co-working interest parties, which contain carry commitments to fund a portion of its future drilling, completing and equipping costs within areas of mutual interest. The Company recorded approximately $205.6 million for Repsol E&P USA, Inc.’s (“Repsol”) carry during the year ended December 31, 2014, and a combined $408.0 million for both Atinum MidCon I, LLC’s (“Atinum”) and Repsol’s drilling carries during the year ended December 31, 2013, which reduced the Company’s capital expenditures for the respective periods. Repsol fully funded its carry commitment in the third quarter of 2014, and the carry commitment from Atinum was fully utilized during the third quarter of 2013. Under the original agreement with Repsol, the carry commitment could have been reduced if a certain number of wells were not drilled within the area of mutual interest during a twelve -month period and the Company failed to drill such wells following a proposal by Repsol to drill the wells. During 2013, the Company temporarily reduced its rate of drilling activity. As a result, the Company drilled less than the targeted number of wells for such twelve -month period, which resulted in Repsol having a right to propose additional wells. In the second quarter of 2014, the Company and Repsol amended their agreement to eliminate Repsol’s right to propose such additional wells in exchange for a commitment by the Company to drill 484 net wells in the area of mutual interest between January 1, 2014 and May 31, 2015, subject to delays due to factors beyond the Company’s control. Under the terms of the amended agreement, the Company agreed to carry Repsol’s future drilling and completion costs in the amount of $1.0 million for each well of the 484 commitment that it did not drill, up to a maximum of $75.0 million in carry costs. As of May 31, 2015, the Company had drilled 453 net wells under this arrangement. As a result, the Company will carry a portion of Repsol’s drilling and completion costs totaling up to approximately $31.0 million for wells drilled in the future in the area of mutual interest. The Company incurred approximately $16.1 million in costs toward this obligation during the year ended December 31, 2015 . Other than the above, the Company has no carry or drilling obligations to Repsol. Costs Excluded from Amortization The following table summarizes the costs, by year incurred, related to unproved properties and pipe inventory, which were excluded from oil and natural gas properties subject to amortization at December 31, 2015 (in thousands): Year Cost Incurred Total 2015 2014 2013 2012 and Prior Property acquisition $ 362,803 $ 197,849 $ 70,304 $ 14,011 $ 80,639 Exploration(1) 34,988 10,698 6,263 17,688 339 Total costs incurred $ 397,791 $ 208,547 $ 76,567 $ 31,699 $ 80,978 ____________________ (1) Includes $34.7 million of pipe inventory costs incurred ( $10.5 million in 2015 , $6.2 million in 2014 and $18.0 million in 2013 and prior years). The Company expects to complete the majority of the evaluation activities within 10 years from the applicable date of acquisition, contingent on the Company’s capital expenditures and drilling program. In addition, the Company’s internal engineers evaluate all properties on at least an annual basis.

Impairment

Impairment	12 Months Ended
	Dec. 31, 2015
Asset Impairment Charges [Abstract]
Impairment	Impairment Property, Plant and Equipment As deemed necessary based on events in 2015, 2014 and 2013, the Company analyzed various property, plant and equipment for impairment. Estimated fair values of these assets were determined using a combination of the discounted cash flow method, recent offers from third-party purchasers or prices of comparable assets with consideration of current market conditions. Given the significance of the unobservable nature of a number of the inputs, these are considered Level 3 on the fair value hierarchy discussed in Note 5 . Oil and Natural Gas Properties. The Company incurred impairments of $4.5 billion and $164.8 million for the years ended December 31, 2015 and 2014, respectively, due to a full cost ceiling limitations. The impairments recorded in 2015 resulted primarily from the significant decrease in oil prices, and to a lesser extent, natural gas prices, that began in the latter half of 2014 and continued in 2015. The impairment in 2014 resulted from the divestiture of the Gulf Properties, as the present value of future net revenues associated with the Gulf Properties exceeded the associated reduction to the full cost pool. Drilling Assets. During 2015, the Company evaluated certain drilling assets for impairment based on the Company’s plans for their future use. As a result of these evaluations, the Company recorded impairments of $37.6 million for the year ended December 31, 2015. During the fourth quarter of 2015, the Company classified drilling and oilfield services assets having a net book value of approximately $16.0 million , as held for sale, which were included in other current assets in the accompanying consolidated balance sheet at December 31, 2015. See Note 7 for additional discussion of assets held for sale. As a result of the Company’s fulfillment of its drilling obligation with the Permian Trust and the downward trend in oil prices that began in the second half of 2014, demand for the Company’s drilling and oilfield services in the Permian region declined significantly. At December 31, 2014, the Company determined the future use of its drilling and oilfield services assets in this region was limited and recorded an impairment of $24.3 million on these assets. During 2014 and 2013, the Company committed to plans to sell various drilling assets. The net book value of these drilling assets was adjusted to fair value, resulting in impairments of $3.1 million and $11.1 million for the years ended December 31, 2014 and 2013, respectively. The remaining net book value of these assets is included in other current assets in the accompanying consolidated balance sheet at December 31, 2014. Gas Treating Plants and Other Midstream Assets. During 2015, 2014 and 2013, the Company evaluated certain midstream pipe inventory, natural gas compressors, gas treating plants and a CO 2 compressor station for impairment when it was determined that their future use was limited. As a result of these evaluations, the Company recorded impairments of $7.1 million , $0.6 million and $12.2 million during the years ended December 31, 2015, 2014 and 2013, respectively, on these assets to reduce their carrying value to fair value. Other Property, Plant and Equipment. In the fourth quarter of 2015, the Company signed an agreement to sell one of its properties located in downtown Oklahoma City, Oklahoma. Because the net book value of the property exceeded the agreed upon sales price, the Company adjusted the carrying value of the property to the agreed upon sales price, resulting in an impairment of $15.4 million for the year ended December 31, 2015. Additionally the company evaluated certain gathering and compression equipment for impairment when it was determined their future use was limited. As a result of these evaluations, the Company recorded an impairment of $0.7 million for the year ended December 31, 2015. In the second quarter of 2013, the Company committed to a plan to sell a corporate asset. The net book value of the corporate asset was adjusted to fair value, resulting in an impairment of $2.9 million during the year ended December 31, 2013. The corporate asset was sold in the fourth quarter of 2013.

Other Assets

Other Assets	12 Months Ended
	Dec. 31, 2015
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Other Assets	Other Assets Other assets consist of the following (in thousands): December 31, 2015 2014 Debt issuance costs, net of amortization $ 72,259 $ 56,445 Deferred tax asset(1) — 95,843 Investments 10,106 11,106 Other — 1,853 Total other assets $ 82,365 $ 165,247 ____________________ (1) The deferred tax asset at December 31, 2015, upon which there is a full valuation allowance, was netted against the deferred tax liability for presentation purposes as a result of the Company’s adoption of ASU 2015-17 in the fourth quarter of 2015. See Note 1 .

Accounts Payable and Accrued Ex

Accounts Payable and Accrued Expenses	12 Months Ended
	Dec. 31, 2015
Payables and Accruals [Abstract]
Accounts Payable and Accrued Expenses	Accounts Payable and Accrued Expenses Accounts payable and accrued expenses consist of the following (in thousands): December 31, 2015 2014 Accounts payable and other accrued expenses $ 231,697 $ 392,500 Accrued interest 73,320 79,704 Production payable 55,260 120,573 Payroll and benefits 42,728 44,496 Convertible perpetual preferred stock dividends 21,572 11,072 Drilling advances 2,295 33,195 Related party 1,545 1,852 Total accounts payable and accrued expenses $ 428,417 $ 683,392

Construction Contract

Construction Contract	12 Months Ended
	Dec. 31, 2015
Contractors [Abstract]
Construction Contract	Construction Contract In the second quarter of 2013, the Company substantially completed the construction of a series of electrical transmission expansion and upgrade projects in northern Oklahoma for a third party. The Company constructed these projects for a contract price of $23.3 million , which included agreed upon change orders. Upon substantial completion of the contract, the Company recognized construction contract revenue and costs equal to the revised contract price of $23.3 million , which are included in the accompanying consolidated statement of operations for the year ended December 31, 2013.

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt consists of the following (in thousands): December 31, 2015 2014 Senior credit facility $ — $ — 8.75% Senior Secured Notes due 2020, including mandatory prepayment feature liabilities of $2,941, and net of $29,842 discount 1,301,098 — Senior Unsecured Notes 8.75% Senior Notes due 2020, net of $3,269 and $4,598 discount, respectively 392,666 445,402 7.5% Senior Notes due 2021, including a premium of $1,944 and $3,486, respectively 759,711 1,178,486 8.125% Senior Notes due 2022 527,737 750,000 7.5% Senior Notes due 2023, net of $1,989 and $3,452 discount, respectively 541,572 821,548 Convertible Senior Unsecured Notes 8.125% Convertible Senior Notes due 2022, including holder conversion feature liabilities of $21,874, and net of $180,751 discount 82,294 — 7.5% Convertible Senior Notes due 2023, including holder conversion feature liabilities of $7,481, and net of $59,549 discount 26,428 — Total debt 3,631,506 3,195,436 Less: current maturities of long-term debt — — Long-term debt $ 3,631,506 $ 3,195,436 See Note 22 for discussion of events occurring related to long-term debt subsequent to December 31, 2015. Senior Credit Facility The senior credit facility, as amended, is available to be drawn on subject to limitations based on its terms and certain financial covenants, as described below. Prior to its amendment and restatement on June 10, 2015, the senior credit facility contained certain financial covenants, including maintenance of agreed upon levels for (a) ratio of total debt secured by assets of the Company and certain of its subsidiaries to EBITDA, which was not permitted to exceed 2.25 :1.00 at each quarter end, calculated using the last four completed fiscal quarters, (b) ratio of EBITDA to interest expense, which was required to be at least 2.00 :1.00 at March 31, 2015 and June 30, 2015, 1.75 :1.00 at September 30, 2015, 1.50 :1.00 at each quarter end from December 31, 2015 to September 30, 2016, and 2.00 :1.00 at December 31, 2016 and thereafter, calculated using the last four completed fiscal quarters, and (c) ratio of current assets to current liabilities, which was required to be at least 1.00 :1.00 at each quarter end. A February 2015 amendment temporarily suspended until June 30, 2016 the financial covenant requiring maintenance of certain levels for the ratio of total net debt to EBITDA. For periods after such time, the ratio of total net debt to EBITDA could not exceed 6.25 :1.00 at June 30, 2016, 6.00 :1.00 at September 30, 2016 and December 31, 2016, 5.50 :1.00 at March 31, 2017 and June 30, 2017, 5.00 :1.00 at September 30, 2017 and December 31, 2017 and 4.50 :1.00 at March 31, 2018 and thereafter, calculated using annualized EBITDA for the fiscal quarter ended June 30, 2016 and the two subsequent fiscal quarters and otherwise calculated using the last four completed fiscal quarters. The senior credit facility was amended and restated on June 10, 2015 (the “June Amendment”). In connection with the June Amendment, the then-existing financial covenants were replaced. As of then and as of December 31, 2015 , the senior credit facility contains financial covenants, including maintenance of agreed upon levels for the (a) ratio of total secured debt under the senior credit facility to EBITDA, which may not exceed 2.00 :1.00 at each quarter end and (b) ratio of current assets to current liabilities, which must be at least 1.0 :1.0 at each quarter end. For the purpose of the current ratio calculation, any amounts available to be drawn under the senior credit facility are included in current assets, and unrealized assets and liabilities resulting from mark-to-market adjustments on the Company’s commodity derivative contracts are disregarded. The senior credit facility matures on the earlier of March 2, 2020 and 91 days prior to the earliest date of any maturity under or mandatory offer to repurchase the Company’s currently outstanding senior notes. Prior and subsequent to the June Amendment, the senior credit facility also contains various covenants that limit the ability of the Company and certain of its subsidiaries to: grant certain liens; make certain loans and investments; make distributions; redeem stock; redeem or prepay debt; merge or consolidate with or into a third party; or engage in certain asset dispositions, including a sale of all or substantially all of the Company’s assets. On August 13, 2015, the senior credit facility was amended to allow the Company to redeem or purchase outstanding Senior Unsecured Notes for up to $200.0 million in cash subject to certain limitations and on October 16, 2015, concurrent with the October borrowing base redetermination, the senior credit facility was further amended to increase the amount of Senior Unsecured Notes the Company may redeem or purchase for cash to $275.0 million from $200.0 million . Additionally, the senior credit facility limits the ability of the Company and certain of its subsidiaries to incur additional indebtedness with certain exceptions. As of and during the year ended December 31, 2015 , the Company was in compliance with all applicable financial covenants under the senior credit facility. The obligations under the senior credit facility are guaranteed by certain Company subsidiaries and are secured by first priority liens on all shares of capital stock of certain of the Company’s material present and future subsidiaries, all of the Company’s intercompany debt, and certain of the Company’s other assets, including proved oil, natural gas and NGL reserves representing at least 80.0% of the discounted present value (as defined in the senior credit facility) of proved oil, natural gas and NGL reserves of the Company. At the Company’s election, interest under the senior credit facility, as amended, is determined by reference to (a) the ICE Benchmark Administration Limited LIBOR (“LIBOR”) plus an applicable margin between 1.750% and 2.750% per annum or (b) the “base rate,” which is the highest of (i) the federal funds rate plus 0.5% , (ii) the prime rate published by Royal Bank of Canada under the senior credit facility or (iii) the one-month Eurodollar rate (as defined in the senior credit facility) plus 1.00% per annum, plus, in each case under scenario (b), an applicable margin between 0.750% and 1.750% per annum. Interest is payable quarterly for base rate loans and at the applicable maturity date for LIBOR loans, except that if the interest period for a LIBOR loan is six months or longer, interest is paid at the end of each three-month period. Quarterly, the Company pays commitment fees assessed at annual rates of 0.5% on any available portion of the senior credit facility. Borrowings and letter of credit obligations under the senior credit facility may not exceed the lower of the committed amount, which is currently $1.0 billion , or the borrowing base, which is $500.0 million and is subject to periodic redeterminations. Prior to the June Amendment, the borrowing base was $900.0 million . This reduction in borrowing base resulted in the write off of approximately $4.9 million of capitalized debt issuance costs. The borrowing base remained unchanged as a result of the October 2015 redetermination. The next scheduled borrowing base redetermination is expected to take place in April 2016; however, as discussed in Note 22, a special redetermination of the borrowing base was made in March 2016. With respect to each redetermination, the administrative agent and the lenders under the senior credit facility consider several factors, including the Company’s proved reserves and projected cash requirements, and make assumptions regarding, among other things, oil and natural gas prices and production. Because the value of the Company’s proved reserves is a key factor in determining the amount of the borrowing base, changing commodity prices and the Company’s success in developing reserves may affect the borrowing base. The Company at times incurs additional costs related to the senior credit facility as a result of amendments to the credit agreement and changes to the borrowing base. The amended senior credit agreement permits the Company and certain of its subsidiaries to incur additional indebtedness in an aggregate principal amount not to exceed $1.75 billion , which may be secured solely by collateral securing the senior credit facility on a junior lien basis. Any junior lien debt shall be subject to the terms and conditions set forth in an intercreditor agreement and shall mature no earlier than January 21, 2020. The borrowing base under the senior credit facility will be reduced by $0.25 for every $1.00 of junior debt incurred above $1.50 billion . The Company had no amounts outstanding under the senior credit facility at December 31, 2015 and $11.0 million in outstanding letters of credit, which reduce availability under the senior credit facility on a dollar-for-dollar basis. Additionally, at December 31, 2015 , the Company had incurred $1.3 billion in junior lien debt subject to an intercreditor agreement as a result of the issuance of Senior Secured Notes in June 2015 and the PGC Senior Secured Notes in October 2015 as described further below. Senior Secured Notes Concurrent with the amendment and restatement of the Company’s senior credit facility discussed above, in June 2015 the Company issued $1.25 billion of 8.75% Senior Secured Notes due 2020. Net proceeds from the issuance were approximately $1.21 billion after deducting offering expenses, a portion of which was used to repay amounts outstanding at that time under the Company’s senior credit facility. The Senior Secured Notes were issued to qualified institutional buyers eligible under Rule 144A of the Securities Act and to persons outside the United States under Regulation S of the Securities Act. Additionally, the Company issued the PGC Senior Secured Notes in conjunction with the acquisition of and termination of a gathering agreement with PGC in October 2015. Because the PGC Senior Secured Notes were issued as partial consideration for the acquisition and termination, these notes were recorded at fair value of approximately $50.3 million ( $78.0 million par value, including mandatory prepayment feature liabilities of $2.8 million , net of $30.5 million discount) upon their issuance. Fair value at issuance was determined based upon the then-current market value of the Senior Secured Notes. The PGC Senior Secured Notes were issued at a discount that is being amortized to interest expense over the term of the Senior Secured Notes. The Company’s Senior Secured Notes bear interest at a fixed rate of 8.75% per annum, payable semi-annually, with the principal due upon maturity. The Senior Secured Notes are redeemable, in whole or in part, prior to their maturity at specified redemption prices and are jointly and severally guaranteed unconditionally, in full, on a second-priority secured basis by certain of the Company’s wholly owned subsidiaries. The Senior Secured Notes are secured by second-priority liens on all of the Company’s and certain of the Company’s wholly owned subsidiaries’ assets that secure the senior credit facility on a first-priority basis; provided, however, the security interest in those assets that secure the Senior Secured Notes and the guarantees will be contractually subordinated to liens thereon that secure the credit facility and certain other permitted indebtedness. Consequently, the Senior Secured Notes and the guarantees will be effectively subordinated to the credit facility and such other indebtedness to the extent of the value of such assets. Debt issuance costs of $39.2 million incurred in connection with the offering of the Senior Secured Notes outstanding at December 31, 2015 are included in other assets in the accompanying unaudited condensed consolidated balance sheet and are being amortized to interest expense over the term of Senior Secured Notes. Maturity Date and Mandatory Prepayment Feature. Pursuant to the indenture, the Senior Secured Notes will mature on June 1, 2020; provided, however, that if on October 15, 2019, the aggregate outstanding principal amount of the unsecured 8.75% Senior Notes due 2020 exceeds $100.0 million , the Senior Secured Notes will mature on October 16, 2019. See further discussion of the mandatory prepayment feature, which with respect to the PGC Senior Secured Notes is an embedded derivative that has been accounted for separately from these notes, at Note 5 and Note 13 . Indenture. The indenture governing the Senior Secured Notes contains covenants that restrict the Company’s ability to take a variety of actions, including limitations on the payment of dividends, incurrence of indebtedness, create liens, enter into consolidations or mergers, purchase or redeem stock or subordinated or unsecured indebtedness, certain dispositions and transfers of assets, transactions with related parties, make investments and refinance certain indebtedness. As of and during the year ended December 31, 2015 , the Company was in compliance with all of the covenants contained in the indenture governing its outstanding Senior Secured Notes. Because the Senior Secured Notes were not issued until June 2015, the covenants contained therein were not applicable during the three-month period ended March 31, 2015. Senior Unsecured Notes The Company’s Senior Unsecured Notes bear interest at a fixed rate per annum, payable semi-annually, with the principal due upon maturity. Certain of the Senior Unsecured Notes were issued at a discount or a premium. The discount or premium is amortized to interest expense over the term of the respective series of Senior Unsecured Notes. The Senior Unsecured Notes are redeemable, in whole or in part, prior to their maturity at specified redemption prices and are jointly and severally guaranteed unconditionally, in full, on an unsecured basis by certain of the Company’s wholly owned subsidiaries. See Note 24 for condensed financial information of the subsidiary guarantors. Debt issuance costs of $48.9 million incurred in connection with the offerings and subsequent registered exchange offers of the Senior Unsecured Notes outstanding, including the impact of write offs in conjunction with the repurchases and exchanges discussed below, are included in other assets in the accompanying consolidated balance sheet at December 31, 2015 and are being amortized to interest expense over the term of the respective series of Senior Unsecured Notes. Indentures. Each of the indentures governing the Company’s Senior Unsecured Notes contains covenants that restrict the Company’s ability to take a variety of actions, including limitations on the incurrence of indebtedness, payment of dividends, investments, asset sales, certain asset purchases, transactions with related parties and consolidations or mergers. As of and during the year ended December 31, 2015 , the Company was in compliance with all of the covenants contained in the indentures governing its outstanding Senior Notes. 2015 Activity Redemption of Senior Unsecured Notes. During the second quarter of 2015, the Company issued to a holder of its 7.5% Senior Notes due 2021 and 8.125% Senior Notes due 2022, approximately 28.0 million shares of the Company’s common stock in exchange for an aggregate $50.0 million principal amount of the notes ( $29.0 million of 7.5% Senior Notes due 2021 and $21.0 million of 8.125% Senior Notes due 2022) and as payment for the interest accrued thereon since the last interest payment date. The exchange resulted in a gain on extinguishment of $17.9 million , which is included in other income on the accompanying consolidated statement of operations for the year ended December 31, 2015 . Repurchase and Exchange of Senior Unsecured Notes. In August 2015, the Company repurchased $250.0 million of its Senior Unsecured Notes comprised of (i) $29.3 million aggregate principal amount of its 8.75% Senior Notes due 2020, (ii) $111.6 million aggregate principal amount of its 7.5% Senior Notes due 2021, (iii) $26.1 million aggregate principal amount of its 8.125% Senior Notes due 2022 and (iv) $83.0 million aggregate principal amount of its 7.5% Senior Notes due 2023, for approximately $94.5 million cash. The repurchase resulted in a gain on extinguishment of $152.0 million , including the write off of $3.2 million of net unamortized debt issuance costs, which is included in other income on the accompanying consolidated statement of operations for the year ended December 31, 2015 . In conjunction with the repurchase, the Company also exchanged $275.0 million of its Senior Unsecured Notes for newly-issued Convertible Senior Unsecured Notes, as discussed further below. In October 2015, the Company repurchased $100.0 million of its Senior Unsecured Notes comprised of (i) $2.2 million aggregate principal amount of its 8.75% Senior Notes due 2020, (ii) $46.6 million aggregate principal amount of its 7.5% Senior Notes due 2021, and (iii) $51.2 million aggregate principal amount of its 7.5% Senior Notes due 2023, for approximately $30.0 million in cash. The repurchase resulted in a gain on extinguishment of $68.7 million , including the write off of $1.2 million of net unamortized debt issuance costs, which is included in other income on the accompanying consolidated statement of operations for the year ended December 31, 2015 . In conjunction with the repurchase, the Company also exchanged approximately $300.0 million of its Senior Unsecured Notes for newly-issued Convertible Senior Unsecured Notes, as discussed further below. 2013 Activity In March 2013, the Company redeemed $365.5 million aggregate principal amount of its 9.875% Senior Notes due 2016 and $750.0 million aggregate principal amount of its 8.0% Senior Notes due 2018 for total consideration of $1,061.34 per $1,000 principal amount and $1,052.77 per $1,000 principal amount, respectively. The premium paid to redeem these notes and the expense incurred to write off the remaining associated unamortized debt issuance costs, totaling $82.0 million , were recorded as a loss on extinguishment of debt in the accompanying consolidated statement of operations for the year ended December 31, 2013. Convertible Senior Unsecured Notes In conjunction with the repurchase of Senior Unsecured Notes in August 2015, the Company also exchanged $275.0 million of its Senior Unsecured Notes, comprised of (i) $15.9 million aggregate principal amount of its 8.75% Senior Notes due 2020, (ii) $40.7 million aggregate principal amount of its 7.5% Senior Notes due 2021, (iii) $101.8 million aggregate principal amounts of its 8.125% Senior Notes due 2022 and (iv) $116.6 million aggregate principal amount of its 7.5% Senior Notes due 2023, for (i) $158.4 million aggregate principal amount of newly-issued 8.125% Convertible Senior Notes due 2022 and (ii) $116.6 million aggregate principal amount of newly-issued 7.5% Convertible Senior Notes due 2023. The exchange resulted in a gain on extinguishment of $189.0 million , including the write off of $4.0 million of net unamortized debt issuance costs, which is included in other income on the accompanying consolidated statement of operations year ended December 31, 2015 . In conjunction with the repurchase of Senior Unsecured Notes in October 2015, the Company exchanged $300.0 million of its Senior Unsecured Notes, comprised of (i) $6.6 million aggregate principal amount of its 8.75% Senior Notes due 2020, (ii) $189.3 million aggregate principal amount of its 7.5% Senior Notes due 2021, (iii) $73.5 million aggregate principal amounts of its 8.125% Senior Notes due 2022 and (iv) $30.6 million aggregate principal amount of its 7.5% Senior Notes due 2023, for (i) $269.4 million aggregate principal amount of newly-issued 8.125% Convertible Senior Notes due 2022 and (ii) $30.6 million aggregate principal amount of newly-issued 7.5% Convertible Senior Notes due 2023. The exchange resulted in a gain on extinguishment of $207.4 million , including the write off of $4.0 million of net unamortized debt issuance costs, which is included in other income on the accompanying consolidated statement of operations year ended December 31, 2015 . The Convertible Senior Unsecured Notes are guaranteed by the same guarantors that guarantee the Senior Unsecured Notes and are subject to covenants and bear payment terms substantially identical to those of the corresponding series of Senior Unsecured Notes of similar tenor, other than the conversion features, described further below, and the extension of the final maturity by one day. The transactions were determined to be an extinguishment of each of the Senior Unsecured Notes exchanged. As such, the newly-issued Convertible Senior Unsecured Notes were recorded at fair value on the date of issuance, which resulted in a discount that is being amortized to interest expense over the term of the respective series of Convertible Senior Unsecured Notes. Debt issuance costs of $6.3 million incurred in connection with the issuance of the Convertible Senior Unsecured Notes, including the impact of write offs in conjunction with the conversions discussed below, are included in other assets in the accompanying consolidated balance sheet at December 31, 2015 and are being amortized to interest expense over the term of the respective series of Convertible Senior Unsecured Notes. Conversion Features. The Convertible Senior Unsecured Notes are convertible, at the option of the holders, into shares of common stock at any time prior to (i) the fifth business day following the date of a mandatory conversion notice, discussed further below, (ii) with respect to Convertible Senior Unsecured Notes called for redemption, the business day immediately preceding the redemption date or (iii) the business day immediately preceding the maturity date. The conversion rate is approximately 363.6 shares of common stock per $1,000 principal amount of the Convertible Senior Unsecured Notes, subject to customary adjustments. With respect to any conversions prior to the first anniversary of the issuance of the Convertible Senior Unsecured notes, in addition to the shares deliverable upon conversion, holders are entitled to receive an early conversion payment equal to the amount of 18 months of interest payable on the applicable series of converted Convertible Senior Unsecured Notes. With respect to any conversion subsequent to the first anniversary of the issuance of the Convertible Senior Unsecured Notes, but on or prior to the second anniversary of the issuance of such Convertible Senior Unsecured Notes, holders are entitled to receive an early conversion payment equal to the amount of 12 months of interest payable on the applicable series of converted Convertible Senior Unsecured Notes. The dilutive effect, if any, of the Convertible Senior Unsecured Notes on the Company’s earnings per share is determined using the if-converted method. See further discussion at Note 20 . See further discussion of the holders’ conversion features, which are embedded derivatives that have been accounted for separately from the Convertible Senior Unsecured Notes, at Note 5 and Note 13 . In addition to the holders’ conversion feature, the Convertible Senior Unsecured Notes contain a provision whereby the Company, subject to compliance with certain conditions, has the right to mandatorily convert the Convertible Senior Unsecured Notes to shares of Company common stock, in whole or in part, at a rate of approximately 363.6 shares of common stock per $1,000 principal amount of Convertible Senior Unsecured Notes, if the volume weighted average price of the Company’s stock exceeds 40.0% of an applicable conversion price of the Convertible Senior Unsecured Notes for a specific period of time. The conversion price threshold, initially set at $1.10 , is subject to certain customary adjustments. No early conversion payments will be made upon a mandatory conversion. Conversions to Common Stock. During the year ended December 31, 2015 , holders of $186.6 million aggregate principal amount ( $54.4 million net of discount and including holders’ conversion feature) of 8.125% Convertible Senior Notes due 2022 and $68.7 million aggregate principal amount ( $19.3 million net of discount and holders’ conversion feature) of 7.5% Convertible Senior Notes due 2023 exercised conversion options applicable to those notes, resulting in the issuance of approximately 92.8 million shares of Company common stock and aggregate cash payments of $30.5 million for accrued interest and early conversion payments. The conversions resulted in a gain on extinguishment of debt totaling $6.1 million , including the write off of $5.2 million of net unamortized debt issuance costs, which is included in other income on the accompanying consolidated statement of operations for year ended December 31, 2015 . Maturities of Long-Term Debt As of December 31, 2015 , $1.7 billion of long-term debt will mature in 2020, with the remainder of long-term debt maturing thereafter; provided, however, that if on October 15, 2019, the aggregate outstanding principal amount of the unsecured 8.75% Senior Notes due 2020 exceeds $100.0 million , the Senior Secured Notes will mature on October 16, 2019.

Derivatives

Derivatives	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives The Company has not designated any of its derivative contracts as hedges for accounting purposes. The Company records all derivative contracts at fair value. Changes in derivative contract fair values are recognized in earnings. Commodity Derivatives The Company is exposed to commodity price risk, which impacts the predictability of its cash flows from the sale of oil and natural gas. The Company seeks to manage this risk through the use of commodity derivative contracts, which allow the Company to limit its exposure to commodity price volatility on a portion of its forecasted oil and natural gas sales. None of the Company’s commodity derivative contracts may be terminated prior to contractual maturity solely as a result of a downgrade in the credit rating of a party to the contract. Cash settlements and valuation gains and losses on commodity derivative contracts are included in (gain) loss on derivative contracts in the consolidated statements of operations. Commodity derivative contracts are settled on a monthly or quarterly basis. Derivative assets and liabilities arising from the Company’s commodity derivative contracts with the same counterparty that provide for net settlement are reported on a net basis in the consolidated balance sheets. At December 31, 2015 , the Company’s commodity derivative contracts consisted of fixed price swaps and collars, which are described below: Fixed price swaps The Company receives a fixed price for the contract and pays a floating market price to the counterparty over a specified period for a contracted volume. Basis swaps The Company receives a payment from the counterparty if the settled price differential is greater than the stated terms of the contract and pays the counterparty if the settled price differential is less than the stated terms of the contract, which guarantees the Company a price differential for oil or natural gas from a specified delivery point. Collars Three-way collars have two fixed floor prices (a purchased put and a sold put) and a fixed ceiling price (call). The purchased put establishes a minimum price unless the market price falls below the sold put, at which point the minimum price would be New York Mercantile Exchange plus the difference between the purchased put and the sold put strike price. The call establishes a maximum price (ceiling) the Company will receive for the volumes under the contract. The Company recorded (gain) loss on commodity derivative contracts of $(73.1) million , $(334.0) million and $47.1 million for the years ended December 31, 2015 , 2014 and 2013 , respectively, as reflected in the accompanying consolidated statements of operations, which includes net cash (receipts) payments upon settlement of $(327.7) million , $32.3 million and $(0.8) million , respectively. Included in these net cash (receipts) payments are $69.6 million and $29.6 million of cash payments related to settlements of commodity derivative contracts with contractual maturities after the year in which they were settled primarily as a result of the sale of the Gulf Properties in February 2014 and the Permian Properties in February 2013, respectively. Derivatives Agreements with Royalty Trusts. During the years ended December 31, 2015, 2014 and 2013, the Company was party to derivatives agreements with the Mississippian Trust I, Permian Trust and Mississippian Trust II to provide each Royalty Trust with the economic effect of certain oil and natural gas derivative contracts entered into by the Company with third parties. The derivatives agreements with the Mississippian Trust I and the Mississippian Trust II contained commodity derivative contracts that covered volumes of oil and natural gas production through December 31, 2015, and the derivatives agreement with the Permian Trust contained commodity derivative contracts that covered volumes of oil production through March 31, 2015. In accordance with the terms of the respective derivatives agreements, the Company novated certain of the commodity derivative contracts underlying the derivatives agreements to each of the Permian Trust and the Mississippian Trust II. As a party to these contracts, the Permian Trust and Mississippian Trust II received payment directly from the counterparty and paid any amounts owed directly to the counterparty during the terms of these novated contracts. To secure its obligations under the respective derivative contracts novated to it, each of the Permian Trust and the Mississippian Trust II granted the counterparties liens on the royalty interests held by each respective Royalty Trust. The derivatives agreements expired upon expiration of the associated underlying derivative contracts and were no longer in effect as of December 31, 2015 . All activity related to the contracts underlying the derivatives agreements with the Royalty Trusts have been included in the Company’s consolidated derivative disclosures. Master Netting Agreements and the Right of Offset. The Company has master netting agreements with all of its commodity derivative counterparties and has presented its derivative assets and liabilities with the same counterparty on a net basis in the consolidated balance sheets. As a result of the netting provisions, the Company's maximum amount of loss under commodity derivative transactions due to credit risk is limited to the net amounts due from its counterparties. As of December 31, 2015 , the counterparties to the Company’s open commodity derivative contracts consisted of eight financial institutions, three of which are also lenders under the Company’s senior credit facility. The Company is not required to post additional collateral under its commodity derivative contracts as certain of the counterparties to the Company’s commodity derivative contracts share in the collateral supporting the Company’s senior credit facility. To secure their obligations under the commodity derivative contracts novated by the Company, the Permian Trust and the Mississippian Trust II gave the counterparties to such contracts a lien on their respective royalty interests. As of December 31, 2015 , the terms of all such novated contracts had expired. The following tables summarize (i) the Company's commodity derivative contracts on a gross basis, (ii) the effects of netting assets and liabilities for which the right of offset exists based on master netting arrangements and (iii) for the Company’s net derivative liability positions, the applicable portion of shared collateral under the senior credit facility (in thousands): December 31, 2015 Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount Assets Derivative contracts - current $ 85,524 $ (1,175 ) $ 84,349 $ — $ 84,349 Derivative contracts - noncurrent — — — — — Total $ 85,524 $ (1,175 ) $ 84,349 $ — $ 84,349 Liabilities Derivative contracts - current $ 1,748 $ (1,175 ) $ 573 $ (573 ) $ — Derivative contracts - noncurrent — — — — — Total $ 1,748 $ (1,175 ) $ 573 $ (573 ) $ — December 31, 2014 Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount Assets Derivative contracts - current $ 291,414 $ — $ 291,414 $ — $ 291,414 Derivative contracts - noncurrent 47,003 — 47,003 — 47,003 Total $ 338,417 $ — $ 338,417 $ — $ 338,417 Liabilities Derivative contracts - current $ — $ — $ — $ — $ — Derivative contracts - noncurrent — — — — — Total $ — $ — $ — $ — $ — At December 31, 2015 , the Company’s open commodity derivative contracts consisted of the following: Oil Price Swaps Notional (MBbls) Weighted Average Fixed Price January 2016 - December 2016 1,464 $ 88.36 Natural Gas Basis Swaps Notional (MMcf) Weighted Average Fixed Price January 2016 - December 2016 10,980 $ (0.38 ) Oil Collars - Three-way Notional (MBbls) Sold Put Purchased Put Sold Call January 2016 - December 2016 2,556 $ 83.14 $ 90.00 $ 100.85 Long-Term Debt - Embedded Derivatives Long-Term Debt Holder Conversion Feature. As discussed further in Note 5 and Note 12 , the Convertible Senior Unsecured Notes contain a conversion feature that is exercisable at the holders’ option. This conversion feature has been identified as an embedded derivative as the feature (i) possesses economic characteristics that are not clearly and closely related to the economic characteristics of the host contract, the Convertible Senior Unsecured Notes, and (ii) separate, stand-alone instruments with the same terms would qualify as derivative instruments. As such, the holders’ conversion feature has been bifurcated and accounted for separately from the Convertible Senior Unsecured Notes. The holders’ conversion feature is recorded at fair value each reporting period with changes in fair value included in interest expense in the accompanying consolidated statement of operations for the year ended December 31, 2015 . Mandatory Prepayment Feature - PGC Senior Secured Notes. As discussed further in Note 5 and Note 12 , the Senior Secured Notes contain a mandatory prepayment feature that is triggered if the outstanding principal amount of the unsecured 8.75% Senior Notes due 2020 exceeds $100.0 million on October 15, 2019. With respect to the PGC Senior Secured Notes, which were issued at a substantial discount, this mandatory prepayment feature has been identified as an embedded derivative as the feature (i) possesses economic characteristics that are not clearly and closely related to the economic characteristics of the host contract, the PGC Senior Secured Notes, and (ii) separate, stand-alone instruments with the same terms would qualify as derivative instruments. As such, the mandatory prepayment feature contained in the PGC Senior Secured Notes has been bifurcated and accounted for separately from those notes. The mandatory prepayment feature contained in the PGC Senior Secured notes is recorded at fair value each reporting period with changes in fair value included in interest expense in the accompanying consolidated statement of operations for the year ended December 31, 2015 . Interest Rate Swaps The Company is exposed to interest rate risk on its long-term fixed rate debt and will be exposed to variable interest rates if it draws on its senior credit facility. Fixed rate debt, where the interest rate is fixed over the life of the instrument, exposes the Company to (i) changes in market interest rates reflected in the fair value of the debt and (ii) the risk that the Company may need to refinance maturing debt with new debt at a higher rate. Variable rate debt, where the interest rate fluctuates, exposes the Company to short-term changes in market interest rates as the Company’s interest obligations on these instruments are periodically redetermined based on prevailing market interest rates, primarily LIBOR and the federal funds rate. Prior to its maturity on April 1, 2013 , the Company had a $350.0 million notional interest rate swap agreement which effectively fixed the variable interest rate on its outstanding floating rate notes at an annual rate of 6.69% for periods prior to their repurchase and redemption in the third quarter of 2012. The interest rate swap was not designated as a hedge. The Company recorded a loss on its interest rate swaps of $0.01 million for the year ended December 31, 2013, which is included in interest expense in the accompanying consolidated statement of operations. Included in the loss for the year ended December 31, 2013 are cash payments upon contract settlement of $2.4 million . Fair Value of Derivatives The following table presents the fair value of the Company’s derivative contracts as of December 31, 2015 and 2014 on a gross basis without regard to same-counterparty netting (in thousands): December 31, Type of Contract Balance Sheet Classification 2015 2014 Derivative assets Oil price swaps Derivative contracts—current $ 68,224 $ 204,072 Natural gas price swaps Derivative contracts—current — 29,648 Natural gas basis swaps Derivative contracts—current — 350 Oil collars—three way Derivative contracts—current 17,300 56,289 Natural gas collars Derivative contracts—current — 1,055 Oil price swaps Derivative contracts—noncurrent — 36,288 Oil collars—three way Derivative contracts—noncurrent — 10,715 Derivative liabilities Natural gas basis swaps Derivative contracts—current (1,748 ) — Long-term debt holder conversion feature Long-term debt (29,355 ) — Mandatory prepayment feature - PGC Senior Secured Notes Long-term debt (2,941 ) — Total net derivative contracts $ 51,480 $ 338,417 See Note 5 for additional discussion of the fair value measurement of the Company’s derivative contracts and Note 12 for discussion of the long-term debt holder conversion and mandatory prepayment features.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The following table presents the balance and activity of the asset retirement obligations for the years ended December 31, 2015 , 2014 and 2013 (in thousands). 2015 2014 2013 Beginning balance $ 54,402 $ 424,117 $ 498,410 Liability incurred upon acquiring and drilling wells 1,662 4,968 5,078 Revisions in estimated cash flows(1) 44,060 (5,848 ) (3,077 ) Liability settled or disposed in current period(2) (1,023 ) (377,927 ) (113,071 ) Accretion 4,477 9,092 36,777 Ending balance 103,578 54,402 424,117 Less: current portion 8,399 — 87,063 Asset retirement obligations, net of current $ 95,179 $ 54,402 $ 337,054 ____________________ (1) Revisions for the year ended December 31, 2015 relate primarily to changes in estimated well lives. (2) Liability settled or disposed for the year ended December 31, 2014, includes $366.0 million associated with the Gulf Properties sold in February 2014, as discussed in Note 3 .

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Operating Leases. The Company has obligations under noncancelable operating leases, primarily for office space and equipment used in drilling and services activities. Total rental expense under operating leases for the years ended December 31, 2015 , 2014 and 2013 was approximately $1.0 million , $1.7 million and $3.6 million , respectively. Future minimum payments under noncancelable operating leases (with initial lease terms exceeding one year) as of December 31, 2015 were as follows (in thousands): Years ending December 31 2016 $ 584 2017 555 2018 485 2019 72 2020 — Thereafter — $ 1,696 Rig Commitments. The Company has contracts with third-party drilling rig operators for the use of their rigs at specified day or footage rates. These commitments are not recorded in the consolidated balance sheets. The minimum future commitment for 2016 was $2.5 million as of December 31, 2015 , with no such commitments subsequent to 2016. Oil and Natural Gas Transportation and Throughput Agreements. The Company has subscribed firm gas transportation service under a transportation service agreement on the Midcontinent Express Pipeline, the term of which continues until July 2019. This commitment is not recorded in the consolidated balance sheets. Under the terms of the agreement, the Company is obligated to pay a demand charge and in exchange, obtains the right to flow natural gas production through this pipeline to more competitive marketing areas. The Company also has oil and natural gas throughput agreements in place, which require fixed fees based on minimum volume requirements for the right to flow oil and natural gas through certain pipelines. The amounts of the required payments related to the transportation and throughput agreements as of December 31, 2015 were as follows (in thousands): Years ending December 31 2016 $ 14,082 2017 13,869 2018 14,163 2019 9,282 2020 1,584 Thereafter 11,088 $ 64,068 Treating Agreement . At December 31, 2015, the Company was party to a 30 -year treating agreement with Occidental Petroleum Corporation (“Occidental”) for the removal of CO 2 from natural gas volumes delivered by the Company. Under the agreement, the Company was required to deliver a total of approximately 3,200 Bcf of CO 2 during the agreement period. The Company was obligated to pay Occidental $0.25 per Mcf to the extent minimum annual CO 2 volume requirements were not met. Through December 31, 2015 , the Company had delivered to Occidental 73.1 Bcf of CO 2, which is 439.6 Bcf less than the cumulative minimum annual CO 2 volume requirements for the same period and had accrued associated annual shortfall penalties of approximately $109.9 million . As discussed in Note 22 , the Company was released from all past, current and future obligations related to this agreement in January 2016. Risks and Uncertainties. The Company’s revenue, profitability and future growth are substantially dependent upon the prevailing and future prices for oil and natural gas, which depend on numerous factors beyond the Company’s control such as overall oil and natural gas production and inventories in relevant markets, economic conditions, the global political environment, regulatory developments and competition from other energy sources. Oil and natural gas prices historically have been volatile, and may be subject to significant fluctuations in the future. The Company enters into commodity derivative arrangements from time to time, depending upon management’s view of opportunities under the then-prevailing current market conditions, in order to mitigate a portion of the effect of this price volatility on the Company’s cash flows. See Note 13 for the Company’s open oil and natural gas commodity derivative contracts. Production targets contained in certain gathering and treating agreements require the Company to incur capital expenditures or make associated shortfall payments, as discussed above. The Company depends on cash flows from operating activities and, as necessary, borrowings under its senior credit facility to fund its capital expenditures. Based on current cash balances, cash flows from operating activities and net borrowings under the senior credit facility in 2016, the Company expects to be able to fund its planned capital expenditures budget, debt service requirements and working capital needs for 2016; however, if current depressed oil or natural gas prices persist for a prolonged period or further decline, they would have a material adverse effect on the Company’s financial position, results of operations, cash flows and quantities of oil, natural gas and NGL reserves that may be economically produced, which would adversely impact the Company’s ability to comply with the financial covenants under its senior credit facility. See Note 12 for discussion of the financial covenants in the senior credit facility and Note 22 for discussion of events occurring related to the senior credit facility subsequent to December 31, 2015. On January 7, 2016, the Company’s stock was delisted from trading on the New York Stock Exchange as a result of having traded below certain required thresholds. Such delisting could impact the Company’s ability to generate funds from equity financing. Litigation and Claims. On April 5, 2011, Wesley West Minerals, Ltd. and Longfellow Ranch Partners, LP filed suit against the Company and SandRidge Exploration and Production, LLC (collectively, the “SandRidge Entities”) in the 83rd District Court of Pecos County, Texas. The plaintiffs, who have leased mineral rights to the SandRidge Entities in Pecos County, allege that the SandRidge Entities have not properly paid royalties on all volumes of natural gas and CO 2 produced from the acreage leased from the plaintiffs. The plaintiffs also allege that the SandRidge Entities have inappropriately failed to pay royalties on CO 2 produced from the plaintiffs' acreage that results from the treatment of natural gas at the Century Plant. The plaintiffs seek approximately $45.5 million in actual damages for the period of time between January 2004 and December 2011, punitive damages and a declaration that the SandRidge Entities must pay royalties on CO 2 produced from the plaintiffs' acreage that results from treatment of natural gas at the Century Plant. The Commissioner of the General Land Office of the State of Texas (“GLO”) is named as an additional defendant in the lawsuit as some of the affected oil and natural gas leases described in the plaintiffs' allegations cover mineral classified lands in which the GLO is entitled to one-half of the royalties attributable to such leases. The GLO has filed a cross-claim against the SandRidge Entities asserting the same claims as the plaintiffs with respect to the leases covering mineral classified lands and seeking approximately $13.0 million in actual damages, inclusive of penalties and interest. On February 5, 2013, the Company received a favorable summary judgment ruling that effectively removes a majority of the plaintiffs' and GLO's claims. On April 29, 2013, the court entered an order allowing for an interlocutory appeal of its summary judgment ruling. The plaintiffs appealed the rulings to the Texas Court of Appeals in El Paso. On November 19, 2014, that Court issued its opinion, which affirmed the trial court’s summary judgment rulings in part, but reversing them in part. The Court of Appeals affirmed the summary judgment rulings in the SandRidge Entities’ favor against the GLO. The Court also affirmed the summary judgment rulings in the SandRidge Entities’ favor against Wesley West Minerals, Ltd., on the largest oil and gas lease involved in the case, which accounted for much of the total damages the plaintiffs are claiming. The Court reversed certain rulings on other leases, thus deciding those matters for the plaintiffs. The parties have petitioned the Supreme Court of Texas for review of the Court of Appeals’ decision. The Company intends to continue to defend the remaining issues in the trial court, as well as future appellate proceedings. At the time of the ruling on summary judgment, the lawsuit was still in the discovery stage and, accordingly, an estimate of reasonably possible losses, if any, associated with the remaining causes of action and those rulings reversed by the Court of Appeals cannot be made until all of the facts, circumstances and legal theories relating to such claims and the SandRidge Entities' defenses are fully disclosed and analyzed. The Company has not established any reserves relating to this action. Between December 2012 and March 2013, seven putative shareholder derivative actions were filed in state and federal court in Oklahoma: • Arthur I. Levine v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on December 19, 2012 in the U.S. District Court for the Western District of Oklahoma • Deborah Depuy v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on January 22, 2013 in the U.S. District Court for the Western District of Oklahoma • Paul Elliot, on Behalf of the Paul Elliot IRA R/O, v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant filed on January 29, 2013 in the U.S. District Court for the Western District of Oklahoma • Dale Hefner v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on January 4, 2013 in the District Court of Oklahoma County, Oklahoma • Rocky Romano v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on January 22, 2013 in the District Court of Oklahoma County, Oklahoma • Joan Brothers v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on February 15, 2013 in the U.S. District Court for the Western District of Oklahoma • Lisa Ezell, Jefferson L. Mangus, and Tyler D. Mangus v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on March 22, 2013 in the U.S. District Court for the Western District of Oklahoma Each lawsuit identified above was filed derivatively on behalf of the Company and names as defendants current and former directors of the Company. The Hefner lawsuit also names as defendants certain current and former directors and senior executive officers of the Company. All seven lawsuits assert overlapping claims - generally that the defendants breached their fiduciary duties, mismanaged the Company, wasted corporate assets, and engaged in, facilitated or approved self-dealing transactions in breach of their fiduciary obligations. The Depuy lawsuit also alleges violations of federal securities laws in connection with the Company allegedly filing and distributing certain misleading proxy statements. The lawsuits seek, among other relief, injunctive relief related to the Company's corporate governance and unspecified damages. On April 10, 2013, the U.S. District Court for the Western District of Oklahoma consolidated the Levine, Depuy, Elliot, Brothers, and Ezell actions (the “Federal Shareholder Derivative Litigation”) under the caption “In re SandRidge Energy, Inc. Shareholder Derivative Litigation,” appointed a lead plaintiff and lead counsel, and ordered the lead plaintiff to file a consolidated complaint by May 1, 2013. On June 3, 2013, the Company and the individual defendants filed their respective motions to dismiss the consolidated complaint. On September 11, 2013, the court granted the defendants’ respective motions to dismiss the consolidated complaint without prejudice, and granted plaintiffs leave to file an amended consolidated complaint. The plaintiffs filed an amended consolidated complaint on October 9, 2013, in which plaintiffs allege that: (i) the Company’s former Chief Executive Officer (“CEO”), Tom Ward, breached his fiduciary duties by usurping corporate opportunities, (ii) certain of the Company’s current and former directors breached their fiduciary duties of care, (iii) Mr. Ward and certain of the Company’s current and former directors wasted corporate assets, (iv) certain entities allegedly affiliated with Mr. Ward aided and abetted Mr. Ward’s breaches of fiduciary duties, (v) Mr. Ward and entities allegedly affiliated with Mr. Ward misappropriated the Company’s confidential and proprietary information, and (vi) entities allegedly affiliated with Mr. Ward were unjustly enriched. On November 15, 2013, the Company and the individual defendants filed their respective motions to dismiss the amended consolidated complaint. On September 22, 2014, the court denied the motion to dismiss filed on behalf of the Company and the director defendants. The court also granted in part and denied in part the respective motions to dismiss filed on behalf of the other defendants. On May 8, 2013, the court stayed the Romano action pending further order of the court. On October 29, 2014, the court granted plaintiff’s application to dismiss the action without prejudice. On September 26, 2014, the Board formed a Special Litigation Committee (“SLC”), composed of two independent and disinterested Company directors, and delegated absolute and final authority to the SLC to review and investigate the claims alleged by the plaintiffs in the Federal Shareholder Derivative Litigation and in the Hefner action, and to determine whether and how those claims should be asserted on the Company’s behalf. On October 7, 2015, the derivative plaintiffs in the Federal Shareholder Derivative Litigation, the SLC, and the individual defendants in the Federal Shareholder Derivative Litigation (Tom Ward, Jim Brewer, Everett Dobson, William Gilliland, Daniel Jordan, Roy Oliver Jr., and Jeffrey Serota), executed a Stipulation of Settlement, which would result in a partial settlement of the Federal Shareholder Derivative Litigation by settling all claims against the individual defendants, subject to certain terms and conditions, including the approval of the court. Under the terms of the proposed partial settlement, the Company would implement or agree to maintain certain corporate governance reforms, and the insurers for the individual defendants would pay $38.0 million to an escrow fund, which would be used to pay certain expenses arising from pending securities litigation and, to the extent funds remain after paying such expenses, would be paid to the Company without any further restrictions on the Company’s use of such funds. The proposed partial settlement expressly provides, among other terms, that the settling defendants deny all allegations of wrongdoing and are entering into the settlement solely to avoid the costs, disruption, uncertainty, and risk of further litigation. On October 9, 2015, the court issued an Order granting preliminary approval of the Stipulation of Settlement and, after notice and a hearing on December 18, 2015, the court issued a Final Judgment and Order on December 22, 2015, granting final approval of the Stipulation of Settlement. The partial settlement did not settle any of the derivative plaintiffs’ claims against non-settling defendants WCT Resources, L.L.C., 192 Investments, L.L.C., and TLW Land & Cattle, L.P in the Federal Shareholder Derivative Litigation. On January 12, 2016, a shareholder who objected to the Stipulation of Settlement filed a notice of appeal of the court’s Final Judgment and Order approving the Stipulation of Settlement. On November 30, 2015, the court stayed the Hefner action until further order of the court. An estimate of reasonably possible losses associated with the Hefner action cannot be made at this time. The Company has not established any reserves relating to this action. On December 5, 2012, James Glitz and Rodger A. Thornberry, on behalf of themselves and all other similarly situated stockholders, filed a putative class action complaint in the U.S. District Court for the Western District of Oklahoma against the Company and certain current and former executive officers of the Company. On January 4, 2013, Louis Carbone, on behalf of himself and all other similarly situated stockholders, filed a substantially similar putative class action complaint in the same court and against the same defendants. On March 6, 2013, the court consolidated these two actions under the caption “In re SandRidge Energy, Inc. Securities Litigation” (the “Securities Litigation”) and appointed a lead plaintiff and lead counsel. On July 23, 2013, plaintiffs filed a consolidated amended complaint, which asserts a variety of federal securities claims against the Company and certain of its current and former officers and directors, among other defendants, on behalf of a putative class of (a) purchasers of SandRidge common stock during the period from February 24, 2011 to November 8, 2012, (b) purchasers of common units of the Mississippian Trust I in or traceable to its initial public offering on or about April 12, 2011, and (c) purchasers of common units of the Mississippian Trust II (together with the Mississippian Trust I, the “Mississippian Trusts”) in or traceable to its initial public offering on or about April 23, 2012. The claims are based on allegations that the Company, certain of its current and former officers and directors, and the Mississippian Trusts, among other defendants, are responsible for making false and misleading statements, and omitting material information, concerning a variety of subjects, including oil and natural gas reserves, the Company's capital expenditures, and certain transactions entered into by companies allegedly affiliated with the Company's former CEO Tom Ward. On May 11, 2015, the court dismissed without prejudice plaintiffs’ claims against the Mississippian Trusts and the underwriter defendants. On August 27, 2015, the court dismissed without prejudice plaintiffs’ claims against the Company and the individual current and former officers and directors, and granted plaintiffs leave to file a second amended consolidated complaint. On October 23, 2015, plaintiffs filed their Second Consolidated Amended Complaint in which plaintiffs assert federal securities claims against the Company and certain of its current and former officers and directors on behalf of a putative class of purchasers of SandRidge common stock during the period between February 24, 2011 and November 8, 2012. The claims are based on allegations that the Company and certain of its current and former officers and directors are responsible for making false and misleading statements, and omitting material information, concerning a variety of subjects, including oil and gas reserves, the Company’s capital expenditures, and certain transactions entered into by companies allegedly affiliated with the Company’s former CEO Tom Ward. Because the Securities Litigation is in the early stages, an estimate of reasonably possible losses associated with it, if any, cannot be made until the facts, circumstances and legal theories relating to the plaintiffs' claims and defendants’ defenses are fully disclosed and analyzed. The Company has not established any reserves relating to the Securities Litigation. Each of the Mississippian Trusts has requested that the Company indemnify it for any losses it may incur in connection with the Securities Litigation. On July 15, 2013, James Hart and 15 other named plaintiffs filed an Amended Complaint in the United States District Court for the District of Kansas in an action undertaken individually and on behalf of others similarly situated against SandRidge Energy, Inc., SandRidge Operating Company, SandRidge E&P, SandRidge Midstream, Inc., and Lariat Services, Inc. In their Amended Complaint, plaintiffs allege that the defendants failed to properly calculate overtime pay for the plaintiffs and for other similarly situated current and former employees. The plaintiffs further allege that the defendants required the plaintiffs and other similarly situated current and former employees to engage in work-related activities without pay. The plaintiffs assert claims against the defendants for (i) violations of the Fair Labor Standards Act, (ii) violations of the Kansas Wage Payment Act, (iii) breach of contract, and (iv) fraud, and seek to recover unpaid wages and overtime pay, liquidated damages, statutory penalties, economic damages, compensatory and punitive damages, attorneys’ fees and costs, and both pre- and post-judgment interest. On October 3, 2013, the plaintiffs filed a Motion for Conditional Collective Action Certification and for Judicial Notice to Class and a Motion to Toll the Statute of Limitations. On October 11, 2013, the defendants filed a Motion to Dismiss and a Motion to Transfer Venue to the United States District Court for the Western District of Oklahoma. On April 2, 2014, the court granted the defendants’ Motion to Dismiss and granted plaintiffs leave to file an amended complaint by April 16, 2014, which they did on such date. On July 1, 2014, the court granted plaintiffs’ Motion for Conditional Collective Action Certification and for Judicial Notice to the Class, and denied plaintiffs’ Motion to Toll the Statute of Limitations. On May 27, 2015, the parties reached an agreement in principle to settle this lawsuit. Pursuant to such agreement, the Company will establish a settlement fund from which to pay participating plaintiffs’ claims as well as plaintiffs’ attorneys’ fees. The proposed settlement agreement is subject to final negotiations between the parties and court approval. During the year ended December 31, 2015, the Company established a $5.1 million reserve for this lawsuit. As previously discussed, on December 18, 2013 , the Company received a subpoena duces tecum from the U.S. Department of Justice in connection with an ongoing investigation of possible violations of antitrust laws in connection with the purchase or lease of land, oil or gas rights. The transactions that have been the subject of the inquiry date from 2012 and prior years. On April 7, 2015, the U.S. Department of Justice notified the Company that it is a target of a grand jury investigation in the Western District of Oklahoma concerning violations of federal antitrust law. The Company is continuing to respond to the government’s requests in connection with the investigation. The Company is unable to predict the outcome of the government's investigation, or any range of loss that could be associated with the resolution of any possible criminal charges or civil claims that may be brought against the Company; however, any governmental action or resolution thereof could be material to the Company. The Company is cooperating with the investigation. On June 9, 2015, the Duane & Virginia Lanier Trust, individually and on behalf of all others similarly situated, filed a putative class action complaint in the U.S. District Court for the Western District of Oklahoma against the Company and certain of its current and former officers and directors, among other defendants, on behalf of a putative class of (a) purchasers of common units of the Mississippian Trust I pursuant or traceable to its initial public offering on or about April 7, 2011, and/or at other times during the time period between April 7, 2011, and November 8, 2012 (the “Class Period”), and (b) purchasers of common units of the Mississippian Trust II pursuant or traceable to its initial public offering on or about April 17, 2012, and/or at other times during the Class Period. The claims are based on allegations that the Company, certain of its current and former officers and directors, and the Mississippian Trusts, among other defendants, are responsible for making false and misleading statements, and omitting material information, concerning a variety of subjects, including oil and natural gas reserves and the Company's capital expenditures. The Company and the other defendants intend to defend this lawsuit vigorously. This lawsuit is in the early stages and, accordingly, an estimate of reasonably possible losses associated with this action, if any, cannot be made until the facts, circumstances and legal theories relating to the plaintiffs' claims and the defendants’ defenses are fully disclosed and analyzed. The Company has not established any reserves relating to this action. Each of the Mississippian Trusts has requested that the Company indemnify it for any losses it may incur in connection with this lawsuit. On July 30, 2015, Barton Gernandt, Jr., individually and on behalf of all others similarly situated, filed a putative class action complaint in the U.S. District Court for the Western District of Oklahoma against the Company and certain of its current and former officers and directors, among other defendants, on behalf of a putative class comprised of all persons, except the named defendants and their immediate family members, who were participants in, or beneficiaries of, the SandRidge Energy, Inc. 401(k) Plan (the “Plan”) at any time between August 2, 2012, and the present, and whose Plan accounts included investments in SandRidge common stock. The plaintiff purports to bring the action both derivatively on the Plan’s behalf pursuant to ERISA §§ 409 and 502, and as a class action pursuant to Rule 23 of the Federal Rules of Civil Procedure. The plaintiff’s claims are based on allegations that the defendants breached their fiduciary duties owed to the Plan and to the Plan participants by allowing the investment of the Plan’s assets in SandRidge common stock when it was otherwise allegedly imprudent to do so based on the financial condition of the Company and the fact the Company’s common stock was artificially inflated because, among other things, the Company materially overstated the amount of oil being produced and the ratio of oil to natural gas in one of its core holdings. On August 19, 2015, Christina A. Cummings, individually and on behalf of all others similarly situated, filed a putative class action complaint in the U.S. District Court for the Western District of Oklahoma against the Company and certain of its current and former officers, among other defendants, on behalf of a putative class comprised of all participants for whose individual accounts the Plan held shares of SandRidge common stock from November 8, 2012, to the present, inclusive. The plaintiff purports to bring the action both derivatively on the Plan’s behalf pursuant to ERISA §§ 409 and 502, and as a class action pursuant to Rule 23 of the Federal Rules of Civil Procedure. The plaintiff’s claims are based on allegations that the defendants breached their fiduciary duties owed to the Plan and to the Plan participants by allowing the investment of the Plan’s assets in SandRidge common stock when it was otherwise allegedly imprudent to do so based on the financial condition of the Company. On September 10, 2015, the Court consolidated this lawsuit with the Gernandt action. On September 14, 2015, Richard A. McWilliams, individually and on behalf of all others similarly situated, filed a putative class action complaint in the U.S. District Court for the Western District of Oklahoma against the Company and certain of its current and former officers and directors, among other defendants, on behalf of a putative class comprised of all persons, except the named defendants and their immediate family members, who were participants in, or beneficiaries of, the Plan at any time between August 2, 2012, and the present, and whose Plan accounts included investments in SandRidge common stock. The plaintiff purports to bring the action both derivatively on the Plan’s behalf pursuant to ERISA §§ 409 and 502, and as a class action pursuant to Rule 23 of the Federal Rules of Civil Procedure. The plaintiff’s claims are based on allegations that the defendants breached their fiduciary duties owed to the Plan and to the Plan participants by allowing the investment of the Plan’s assets in SandRidge common stock when it was otherwise allegedly imprudent to do so based on the financial condition of the Company and the fact the Company’s common stock was artificially inflated because, among other things, the Company materially overstated the amount of oil being produced and the ratio of oil to natural gas in one of its core holdings. On September 24, 2015, the Court consolidated this lawsuit with the Gernandt action. On November 24, 2015, the plaintiffs filed a Consolidated Class Action Complaint in the consolidated Gernandt action. The Company intends to defend this consolidated lawsuit vigorously. This lawsuit is in the early stages and, accordingly, an estimate of reasonably possible losses associated with this action, if any, cannot be made until the facts, circumstances and legal theories relating to the plaintiffs' claims and the defendants’ defenses are fully disclosed and analyzed. The Company has not established any reserves relating to this action. On November 18, 2015, Mickey Peck, on behalf of himself and others similarly situated, filed a First Amended Collective Action Complaint in the United States District Court for the Western District of Oklahoma against SandRidge Energy, Inc., and SandRidge Operating Company for violations of the Fair Labor Standards Act. Plaintiff alleges that the Company improperly classified certain of its consultants as independent contractors rather than as employees and, therefore, improperly paid such consultants a day rate without paying any overtime compensation. On January 14, 2016, the Court entered an Order conditionally certifying the class and providing for notice. This lawsuit is in the early stages and, accordingly, an estimate of reasonably possible losses associated with this action, if any, cannot be made until the facts, circumstances and legal theories relating to the plaintiffs' claims and the defendants’ defenses are fully disclosed and analyzed. The Company has not established any reserves relating to this action. On January 12, 2016, Lisa Griggs and April Marler, on behalf of themselves and all other similarly situated, filed a putative class action petition in the District Court of Logan County, Oklahoma, against SandRidge Exploration and Production, LLC, and certain other oil and gas exploration companies. In their petition, plaintiffs assert various tort claims based upon purported damage and loss resulting from earthquakes allegedly caused by the defendants’ operations of wastewater disposal wells. Plaintiffs seek to certify a class of “all residents of Oklahoma owning real property from 2011 through the time the Class is certified.” On February 16, 2016, the defendants filed a Notice of Removal of the lawsuit to the United States District Court for the Western District of Oklahoma. This lawsuit is in the early stages and, accordingly, an estimate of reasonably possible losses associated with this action, if any, cannot be made until the facts, circumstances and legal theories relating to the plaintiffs' claims and the defendants’ defenses are fully disclosed and analyzed. The Company has not established any reserves relating to this action. On February 12, 2016, Brenda Lene and Jon Darryn Lene filed a petition in the District Court of Logan County, Oklahoma, against SandRidge Exploration and Production, LLC, and certain other oil and gas exploration companies. In their petition, plaintiffs assert various tort claims based on their allegations that their home suffered damages due to earthquakes allegedly caused by the defendants’ operations of wastewater disposal wells. This lawsuit is in the early stages and, accordingly, an estimate of reasonably possible losses associated with this action, if any, cannot be made until the facts, circumstances and legal theories relating to the plaintiffs' claims and the defendants’ defenses are fully disclosed and analyzed. The Company has not established any reserves relating to this action. On March 3, 2016, Brian Thieme, on behalf of himself and all others similarly situated, filed a putative class action petition in the United States District Court for the Western District of Oklahoma against SandRidge Energy, Inc. and the Company’s former CEO, Tom L. Ward, among other defendants. Plaintiff alleges that, commencing on or around December 27, 2007, and continuing until at least March 31, 2012, the defendants conspired to rig bids and depress the market for the purchases of oil and natural gas leasehold interests and properties containing producing oil and natural gas wells located in certain areas of Oklahoma, Texas, Colorado and Kansas, in violation of Sections 1 and 3 of the Sherman Antitrust Act. Plaintiff seeks to certify two separate and distinct classes of members. This lawsuit is in the early stages and, accordingly, an estimate of reaso

Equity

Equity	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Equity	Equity Preferred Stock The following table presents information regarding the Company’s preferred stock (in thousands): December 31, 2015 2014 Shares authorized, $0.001 par value 50,000 50,000 Shares outstanding at end of period 8.5% Convertible perpetual preferred stock 2,650 2,650 7.0% Convertible perpetual preferred stock(1) 2,770 3,000 ____________________ (1) For the year ended December 31, 2015 , approximately 230,500 shares were converted into approximately 3.0 million shares of the Company’s common stock. All of the outstanding shares of the Company’s convertible perpetual preferred stock were issued in private transactions, but are now freely tradable, to the extent not owned by affiliates. In December 2014, all shares of the Company’s outstanding 6.0% convertible preferred stock converted automatically into shares of the Company’s common stock at the then-prevailing conversion rate, resulting in the issuance of approximately 18.4 million shares of common stock. Each outstanding share of convertible perpetual preferred stock is convertible at the holder’s option at any time into shares of the Company’s common stock at the specified conversion rate, subject to customary adjustments in certain circumstances. Each holder is entitled to an annual dividend payable semi-annually in cash, common stock or a combination thereof, at the Company’s election. The Company may cause all outstanding shares of the convertible perpetual preferred stock to convert automatically into common stock at the prevailing conversion rate dependent on certain factors, including the Company’s stock trading above specified prices for a set period. The convertible perpetual preferred stock is not redeemable by the Company at any time. The following table summarizes information about each series of the Company’s convertible perpetual preferred stock outstanding at December 31, 2015 : Convertible Perpetual Preferred Stock 8.5% 7.0% Liquidation preference per share $ 100.00 $ 100.00 Annual dividend per share $ 8.50 $ 7.00 Conversion rate per share to common stock 12.4805 12.8791 Preferred Stock Dividends. In accordance with the terms governing the Company’s convertible perpetual preferred stock, dividends may be paid in cash or with shares of the Company’s common stock at the Company’s election. Preferred stock dividend payments and accruals for the Company’s 8.5% , 7.0% and 6.0% convertible perpetual preferred stock for the years ended December 31, 2015 , 2014 and 2013 are as follows: December 31, 2015 2014 2013 (In thousands) 8.5% Convertible perpetual preferred stock Dividends paid in cash $ 11,262 $ 22,525 $ 22,525 Dividends satisfied in shares of common stock(1) $ 11,262 $ — $ — Accrued dividends at period end $ 8,447 $ 8,447 $ 8,447 7.0% Convertible perpetual preferred stock Dividends paid in cash $ — $ 21,000 $ 21,000 Dividends satisfied in shares of common stock(2) $ 10,500 $ — $ — Accrued dividends at period end $ 13,125 $ 2,625 $ 2,625 Dividends in arrears(3) $ 10,500 $ — $ — 6.0% Convertible perpetual preferred stock (4) Dividends paid in cash $ — $ 12,000 $ 12,000 Accrued dividends at period end $ — $ — $ 5,500 ____________________ (1) For the year ended December 31, 2015 , the Company paid a semi-annual dividend by issuing approximately 18.6 million shares of common stock. For purposes of the dividend payment, the value of each share issued was calculated as 95% of the average volume-weighted share price for the 15 trading day period ending July 29, 2015. Based upon the common stock’s closing price on August 17, 2015, the common stock issued had a market value of approximately $9.5 million , ( $3.58 per outstanding share at the time the dividend was paid) that resulted in a difference between the fixed rate semi-annual dividend and the value of shares issued of approximately $1.8 million , which was recorded as a reduction to preferred stock dividends in the accompanying condensed consolidated statement of operations. (2) For the year ended December 31, 2015 , the Company paid a semi-annual dividend by issuing approximately 5.7 million shares of common stock. For purposes of the dividend payment, the value of each share issued was calculated as 95% of the average volume-weighted share price for the 15 trading day period ending April 28, 2015. Based upon the common stock’s closing price on May 15, 2015, the common stock issued had a market value of approximately $6.7 million , ( $2.23 per outstanding share at the time the dividend was paid) that resulted in a difference between the fixed rate semi-annual dividend and the value of shares issued of approximately $3.8 million , which was recorded as a reduction to preferred stock dividends in the accompanying condensed consolidated statement of operations. (3) In the third quarter of 2015, the Company announced the suspension of payment of the semi-annual dividend on shares of its 7.0% convertible perpetual preferred stock. (4) The final dividend payment for the 6.0% convertible preferred stock was made during 2014. Paid and unpaid dividends included in the calculation of (loss applicable) income available to the Company’s common stockholders and the Company’s basic (loss) earnings per share calculation for the years ended December 31, 2015 , 2014 and 2013 are presented in the accompanying condensed consolidated statements of operations. See Note 20 for discussion of the Company’s (loss) earnings per share calculation. Common Stock In June 2015, the Company's stockholders approved an amendment to the Company's Certificate of Incorporation, to increase the number of shares of capital stock the Company is authorized to issue from 850.0 million ( 800.0 million shares of common stock and 50.0 million shares of preferred stock), par value $0.001 to 1.85 billion ( 1.80 billion shares of common stock and 50.0 million shares of preferred stock), par value $0.001 . The following table presents information regarding the Company’s common stock (in thousands): December 31, 2015 2014 Shares authorized 1,800,000 800,000 Shares outstanding at end of period 633,471 484,819 Shares held in treasury 2,113 1,113 Redemption of Senior Unsecured Notes. During the year ended December 31, 2015 , the Company issued approximately 28.0 million shares of common stock in exchange for $50.0 million in Senior Unsecured Notes. See Note 12 for additional discussion of the redemption of Senior Unsecured Notes. Conversions of Convertible Senior Unsecured Notes. During the year ended December 31, 2015 , the Company issued approximately 92.8 million shares of common stock upon the exercise of conversion options by holders of approximately $255.3 million in par value of the Convertible Senior Unsecured Notes. The Company recorded the issuance of common shares at fair value on the various dates the exchanges occurred. See Note 12 for additional discussion of the Convertible Senior Unsecured Notes transactions. Stock Repurchase Program. In 2014, the Company’s Board of Directors approved a share repurchase program under which the Company can repurchase up to $200.0 million of the Company’s common stock. Under the program’s terms, shares may be repurchased on the open market, through privately negotiated transactions such as block trades, or by other means as determined by the Company’s management and in accordance with the requirements of the Securities and Exchange Commission. The timing and actual number of shares repurchased will depend on a variety of factors including price, corporate and regulatory requirements, and other conditions. There is no fixed termination date for this repurchase program, and the repurchase program may be suspended or discontinued at any time. Payment for shares repurchased under the program will be funded using the Company's working capital. During the year ended December 31, 2014, 27.4 million shares totaling $111.3 million , net of $0.5 million in broker fees and commissions, were repurchased under the program at prices equivalent to the then current market price and immediately retired. As the Company had an accumulated deficit balance, the excess of the repurchase price over the par value was fully applied to additional paid-in capital. Stockholder Rights Plan. On November 19, 2012, the Company’s Board adopted a stockholder rights plan pursuant to which the Board authorized and declared to stockholders of record on November 29, 2012 a dividend of one preferred share purchase right (the “Right”) for each outstanding share of common stock. Effective April 29, 2013, at the direction of the Board, the Company amended a stockholder rights plan, adopted in the fourth quarter of 2012, to accelerate the expiration date of the Rights to April 29, 2013, resulting in the termination of the stockholder rights plan. See Note 17 for discussion of the Company’s share-based compensation. Treasury Stock The Company makes required statutory tax payments on behalf of employees when their restricted stock awards vest and then withholds a number of vested shares of common stock having a value on the date of vesting equal to the tax obligation. The following table shows the number of shares withheld for taxes and the associated value of those shares for the years ended December 31, 2015 , 2014 and 2013 . These shares were accounted for as treasury stock when withheld, and then immediately retired. Year Ended December 31, 2015 2014 2013 (In thousands) Number of shares withheld for taxes 1,872 1,034 5,679 Value of shares withheld for taxes $ 2,428 $ 6,373 $ 30,126 Shares of Company common stock held as assets in a trust for the Company’s non-qualified deferred compensation plan are accounted for as treasury shares. These shares are not included as outstanding shares of common stock for accounting purposes. For corporate purposes, including for the purpose of voting at Company stockholder meetings, these shares are considered outstanding and have voting rights, which are exercised by the Company. Stockholder Receivable The Company is party to a settlement agreement relating to a third-party claim against its former CEO under Section 16(b) of the Securities Exchange Act of 1934, as amended. Based on the nature of the settlement as well as the former CEO’s position as an officer of the Company at the time of the settlement, the receivable related to this settlement is classified as a component of additional paid-in capital in the accompanying consolidated balance sheets. The remaining amount receivable under the agreement as of December 31, 2015 and 2014 was $1.3 million and $2.5 million , respectively.

Share-Based Compensation

Share-Based Compensation	12 Months Ended
	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-Based Compensation	Share-Based Compensation The Company issues share-based compensation awards including restricted common stock awards, restricted stock units, performance units and performance share units under the SandRidge Energy, Inc. 2009 Incentive Plan. Total share-based compensation expense is measured using the grant date fair value for equity-classified awards and using the fair value at period end for liability-classified awards. For the years ended December 31, 2015 , 2014 and 2013 , the Company recognized share-based compensation expense of $21.7 million , $22.6 million and $90.2 million , respectively, net of $5.9 million , $6.0 million and $5.6 million capitalized, respectively. Amounts recognized during the year ended December 31, 2013 include approximately $48.5 million recognized in connection with the separation of certain former executives from the Company. Restricted Common Stock Awards The Company’s restricted common stock awards generally vest over a four -year period, subject to certain conditions, and are valued based upon the market value of the Company’s common stock on the date of grant. The following table presents a summary of the Company’s unvested restricted stock awards. Number of Shares Weighted- Average Grant Date Fair Value (In thousands) Unvested restricted shares outstanding at December 31, 2012 15,328 $ 8.07 Granted 7,462 $ 6.32 Vested (13,395 ) $ 7.85 Forfeited / Canceled (1,752 ) $ 7.33 Unvested restricted shares outstanding at December 31, 2013 7,643 $ 6.92 Granted 6,367 $ 6.17 Vested (3,432 ) $ 7.04 Forfeited / Canceled (2,022 ) $ 6.60 Unvested restricted shares outstanding at December 31, 2014 8,556 $ 6.39 Granted 2,928 $ 0.88 Vested (5,186 ) $ 4.95 Forfeited / Canceled (672 ) $ 6.38 Unvested restricted shares outstanding at December 31, 2015 5,626 $ 4.85 As of December 31, 2015 , the Company’s unrecognized compensation cost related to unvested restricted stock awards was $18.0 million . Such cost is expected to be recognized over a weighted-average period of 1.9 years. The Company’s restricted stock awards are equity-classified awards. Restricted Stock Units During the year ended December 31, 2015 , the Company granted restricted stock units that vest over a maximum of four years and will be settled in cash, shares of Company common stock or a combination of common stock and cash. Restricted Stock Units - Settled in Cash or Stock . The following table presents a summary of the Company’s unvested restricted stock units which may be settled in shares of the Company’s common stock, cash or some combination of common stock and cash at the Company’s election. These restricted stock units are liability-classified awards, which vest ratably over a maximum four -year period from the date of grant and were valued at December 31, 2015 based upon the Company’s period end common stock price. Number of Units Fair Value per Unit at December 31, 2015 (In thousands) Unvested units outstanding at December 31, 2014 — Granted 11,095 Vested(1) (2,200 ) Forfeited / Canceled (767 ) Unvested units outstanding at December 31, 2015 8,128 $ 0.20 ____________________ (1) Restricted stock units which vested during the year ended December 31, 2015 were settled by the issuance of common stock. As of December 31, 2015 , the Company’s unrecognized compensation cost related to the unvested restricted stock units noted above was $0.9 million and is expected to be recognized over a weighted-average period of 3.2 years. Restricted Stock Units - Settled in Cash. The following table presents a summary of the Company’s unvested restricted stock units which will be settled in cash at the end of each vesting period for an amount based on the Company’s common stock price as of the vesting date. These restricted stock units are liability-classified awards and generally vest over a two -year period ( 40% at the end of the first year and 60% at the end of the second year). The restricted stock units were valued based upon the Company’s period end common stock price, discounted using a credit spread ( 10.6% at December 31, 2015 ) that was determined based upon an analysis of the historical option adjusted spread for the Company’s outstanding senior notes and the outstanding long-term debt of comparable companies. Number of Units Fair Value per Unit at December 31, 2015 (In thousands) Unvested units outstanding at December 31, 2014 — Granted 3,104 Vested (979 ) Forfeited / Canceled (122 ) Unvested units outstanding at December 31, 2015 2,003 $ 0.04 - $ 0.20 As of December 31, 2015 , the Company’s unrecognized compensation cost related to unvested two-year restricted stock units was $0.2 million . Such cost is expected to be recognized over a weighted-average period of 1.0 years. Performance Units and Performance Share Units The Company periodically grants performance units and performance share units to certain members of senior management which vest ratably over a performance period of approximately three years with cash settlements, if any, occurring at the end of the performance period. The value, and ultimate cash settlement, of the performance units is determined based upon the Company’s total shareholder return relative to that of a predetermined peer group over a specific performance period. The Company’s performance units and performance share units are liability-classified awards. The performance units and performance share units are valued for accounting purposes using a Monte Carlo simulation based on certain assumptions including (i) a volatility assumption based on the historical realized price volatility of the Company’s common stock and the common stock of the predetermined peer group and (ii) a risk-free interest rate based on the U.S. Treasury bond yield for a term commensurate with the approximate remaining vesting period for each grant. Performance Units. The following table presents a summary of the fair values of the performance units granted during the years ended December 31, 2014 and 2013 and the related assumptions for all outstanding performance units at December 31, 2015 and 2014 . December 31, 2015 2014 Volatility factor 120.0 % 55.6 % Weighted-average risk-free interest rate 0.7 % 0.5 % Weighted-average fair value per unit $ 1.08 $ 13.85 Performance unit activity for the years ended December 31, 2015 , 2014 and 2013 was as follows (in thousands): December 31, 2015 2014 2013(1) Outstanding at January 1 66 31 — Granted — 47 31 Vested (28 ) — — Forfeited /canceled — (12 ) — Outstanding at December 31 38 66 31 Performance period ending December 31, 2015 Vested — 9 12 Unvested — 19 19 Performance period ending December 31, 2016 Vested 26 13 — Unvested 12 25 — ____________________ (1) The 2013 performance units fully vested on December 31, 2015, with no amounts paid. As of December 31, 2015 , the Company’s unrecognized compensation cost related to performance units granted in 2014 was insignificant and is expected to be recognized over the remaining 1.0 year term of the awards. Performance Share Units. During the year ended December 31, 2015 , the Company granted performance share units to certain members of senior management. The following table presents a summary of the fair values of the performance share units granted and the related assumptions for all outstanding performance share units at December 31, 2015 . December 31, 2015 Volatility factor 95.3 % Weighted-average risk-free interest rate 1.1 % Weighted-average fair value per unit $ 0.10 Performance share unit activity for the year ended December 31, 2015 was as follows: Number of Performance Share Units (In thousands) Outstanding at December 31, 2014 — Granted 2,044 Forfeited /canceled (151 ) Outstanding at December 31, 2015 1,893 Performance period ending December 31, 2017 Vested 695 Unvested 1,198 As of December 31, 2015 , the Company’s unrecognized compensation cost related to performance share units granted in 2015 units was $0.1 million . Such cost is expected to be recognized over the remaining 2.0 year term of the awards.

Incentive and Deferred Compensa

Incentive and Deferred Compensation Plans	12 Months Ended
	Dec. 31, 2015
Compensation Related Costs [Abstract]
Incentive and Deferred Compensation Plans	Incentive and Deferred Compensation Plans Annual Incentive Plan. In June 2013, the Compensation Committee of the Company’s Board approved an annual incentive plan effective June 2013 for all employees and discontinued the Company’s then existing cash bonus program with final payments under the program of approximately $10.9 million made in July 2013. For certain members of management, the annual incentive plan incorporates objective performance criteria, individual performance goals and competitive target award levels for the 2015 performance year with payout percentages ranging from 0% to 200% of specified target levels based on actual performance. As of December 31, 2015 and 2014 , the Company had accrued approximately $21.6 million and $21.1 million , respectively, for the annual incentive for all employees, including an accrual for an annual incentive for specified members of management based on actual performance compared to target levels specified in the annual incentive plan. The annual incentive plan was replaced in January 2016 by the Company’s newly-implemented performance incentive plan. See Note 22 . Deferred Compensation Plans. The Company maintains a 401(k) retirement plan for its employees. Under the Plan, eligible employees may elect to defer a portion of their earnings up to the maximum allowed by regulations promulgated by the Internal Revenue Service (“IRS”). The Company made matching contributions to the plan through cash purchases of Company stock equal to 100% on the first 10% employee deferred wages for the years ended December 31, 2015 and 2014 and 100% on the first 15% of employee deferred wages for the year ended December 31, 2013. Retirement plan expense for the years ended December 31, 2015 , 2014 and 2013 was approximately $7.9 million , $8.7 million and $11.0 million , respectively. The Company maintains a non-qualified deferred compensation plan that allows eligible highly compensated employees to elect to defer income exceeding the IRS annual limitations on qualified 401(k) retirement plans. The Company made matching contributions on non-qualified contributions up to a maximum of 10% of employee compensation for the years ended December 31, 2015 and 2014 and 15% of employee compensation for the year ended December 31, 2013. For the years ended December 31, 2015 , 2014 and 2013 , employer contributions of cash purchases of Company stock were approximately $2.9 million , $2.0 million and $2.7 million , respectively. Any assets placed in trust by the Company to fund future obligations of the Company’s non-qualified deferred compensation plan are subject to the claims of creditors in the event of insolvency or bankruptcy, and participants are general creditors of the Company as to their own deferred compensation in, and the Company’s contributions to, the plan.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The Company’s income tax provision (benefit) consisted of the following components for the years ended December 31, 2015 , 2014 and 2013 (in thousands): Year Ended December 31, 2015 2014 2013 Current Federal $ — $ (1,160 ) $ 3,842 State 123 (1,133 ) 1,842 123 (2,293 ) 5,684 Deferred Federal — — — State — — — — — — Total provision (benefit) 123 (2,293 ) 5,684 Less: income tax provision attributable to noncontrolling interest 90 283 308 Total provision (benefit) attributable to SandRidge Energy, Inc. $ 33 $ (2,576 ) $ 5,376 A reconciliation of the provision (benefit) for income taxes at the statutory federal tax rate to the Company’s actual income tax benefit is as follows for the years ended December 31, 2015 , 2014 and 2013 (in thousands): 2015 2014 2013 Computed at federal statutory rate $ (1,512,325 ) $ 122,362 $ (178,078 ) State taxes, net of federal benefit (19,988 ) 4,145 (886 ) Non-deductible expenses 816 1,895 2,589 Non-deductible debt costs 10,228 — — Stock-based compensation 6,700 1,467 7,611 Net effects of consolidating the non-controlling interests’ tax provisions 218,196 (34,614 ) (13,901 ) Change in valuation allowance 1,296,405 (96,769 ) 188,599 Other 1 (1,062 ) (558 ) Total provision (benefit) attributable to SandRidge Energy, Inc. $ 33 $ (2,576 ) $ 5,376 Deferred income taxes are provided to reflect the future tax consequences of temporary differences between the tax basis of assets and liabilities and their reported amounts in the financial statements. The Company’s deferred tax assets have been reduced by a valuation allowance due to a determination made that it is more likely than not that some or all of the deferred assets will not be realized based on the weight of all available evidence. As of December 31, 2015 , 2014 and 2013 the balance of the valuation allowance was $2.0 billion , $649.6 million , and $753.5 million , respectively. The Company continues to closely monitor and weigh all available evidence, including both positive and negative, in making its determination whether to maintain a valuation allowance. As a result of the significant weight placed on the Company’s cumulative negative earnings position, the Company continued to maintain the full valuation allowance against its net deferred tax asset at December 31, 2015 . Thus, the Company’s effective tax rate and tax expense for the year ended December 31, 2015 continue to be low as a result of the Company not recognizing an income tax benefit associated with its net loss from the same period. Significant components of the Company’s deferred tax assets and liabilities are as follows (in thousands): December 31, 2015 2014 Deferred tax liabilities Investments(1) $ 138,310 $ 272,902 Property, plant and equipment — 364,576 Derivative contracts 30,989 113,735 Long-term debt 10,017 — Total deferred tax liabilities 179,316 751,213 Deferred tax assets Property, plant and equipment 807,275 — Allowance for doubtful accounts 18,702 19,086 Net operating loss carryforwards 1,190,799 1,265,458 Compensation and benefits 18,607 19,867 Alternative minimum tax credits and other carryforwards 44,302 43,840 Asset retirement obligations 38,314 21,946 CO 2 under-delivery shortfall penalty 40,654 27,674 Other 4,305 2,934 Total deferred tax assets 2,162,958 1,400,805 Valuation allowance (1,983,642 ) (649,592 ) Net deferred tax liability $ — $ — ____________________ (1) Includes the Company’s deferred tax liability resulting from its investment in the Royalty Trusts. See Note 4 for further discussion of the Royalty Trusts. As of December 31, 2015 , the Company had approximately $9.3 million of alternative minimum tax credits available that do not expire. In addition, the Company had approximately $3.2 billion of federal net operating loss carryovers that expire during the years 2025 through 2035 . Excess tax benefits of approximately $17.7 million associated with the vesting of restricted stock awards are included in the federal net operating loss carryovers, but will not be recognized as a tax benefit recorded to additional paid-in capital until realized. Internal Revenue Code (“IRC”) Section 382 addresses company ownership changes and specifically limits the utilization of certain deductions and other tax attributes on an annual basis following an ownership change. The Company experienced ownership changes within the meaning of IRC Section 382 during 2008 and 2010 that subjected certain of the Company’s tax attributes, including $929.4 million of federal net operating loss carryforwards, to an IRC Section 382 limitation. The limitation could result in all or a portion of the remaining $552.6 million limited net operating loss carryforwards expiring unused. The limitation did not result in a current federal tax liability at December 31, 2015 . At December 31, 2015 and 2014 , the Company had a liability of approximately $0.1 million for unrecognized tax benefits. A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows (in thousands): December 31, 2015 2014 Unrecognized tax benefit at January 1 $ 77 $ 1,382 Changes to unrecognized tax benefits related to a prior year 4 (17 ) Decreases to unrecognized tax benefits for settlements with tax authorities — (1,288 ) Unrecognized tax benefit at December 31 $ 81 $ 77 Consistent with its policy to record interest and penalties on income taxes as a component of the income tax provision, the Company has included insignificant amounts of accrued gross interest with respect to unrecognized tax benefits in its accompanying consolidated statements of operations during the years ended December 31, 2015 , 2014 and 2013 . The Company does not expect a significant change in its gross unrecognized tax benefits balance within the next 12 months. The Company’s only taxing jurisdiction is the United States (federal and state). The Company’s tax years 2012 to present remain open for federal examination. Additionally, tax years 2005 through 2011 remain subject to examination for the purpose of determining the amount of federal net operating loss and other carryforwards. The number of years open for state tax audits varies, depending on the state, but are generally from three to five years.

(Loss) Earnings per Share

(Loss) Earnings per Share	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
(Loss) Earnings per Share	(Loss) Earnings per Share Basic earnings per share are computed using the weighted average number of common shares outstanding during the period. Diluted earnings per share are computed using the weighted average shares outstanding during the period, but also include the dilutive effect of awards of restricted stock and restricted stock units, using the treasury stock method, and outstanding convertible perpetual preferred stock and convertible senior notes, using the if-converted method. The following table summarizes the calculation of weighted average common shares outstanding used in the computation of diluted earnings per share, for the years ended December 31, 2015 , 2014 and 2013 (in thousands): Net (Loss) Income Weighted Average Shares (Loss) Earnings Per Share (In thousands, except per share amounts) Year Ended December 31, 2015 Basic loss per share $ (3,735,495 ) 521,936 $ (7.16 ) Effect of dilutive securities Restricted stock and units(1) — — Convertible preferred stock(2) — — Convertible senior unsecured notes(3) — — Diluted loss per share $ (3,735,495 ) 521,936 $ (7.16 ) Year Ended December 31, 2014 Basic earnings per share $ 203,260 479,644 $ 0.42 Effect of dilutive securities Restricted stock — 2,181 Convertible preferred stock(2) 6,500 17,918 Diluted earnings per share $ 209,760 499,743 $ 0.42 Year Ended December 31, 2013 Basic loss per share $ (609,414 ) 481,148 $ (1.27 ) Effect of dilutive securities Restricted stock(4) — — Convertible preferred stock(5) — — Diluted loss per share $ (609,414 ) 481,148 $ (1.27 ) ____________________ (1) No incremental shares of potentially dilutive restricted stock awards or units were included for the year ended December 31, 2015 as their effect was antidilutive under the treasury stock method. (2) Potential common shares related to the Company’s outstanding 8.5% and 7.0% convertible perpetual preferred stock covering 71.2 million and 71.7 million shares for the years ended December 31, 2015 and 2014 , respectively, were excluded from the computation of (loss) earnings per share because their effect would have been antidilutive under the if-converted method. (3) Potential common shares related to the Company’s outstanding 8.125% and 7.5% Convertible Senior Unsecured Notes covering 48.5 million shares for the year ended December 31, 2015 were excluded from the computation of loss per share because their effect would have been antidilutive under the if-converted method. (4) Restricted stock awards covering 0.5 million shares were excluded from the computation of loss per share because their effect would have been antidilutive. (5) Potential common shares related to the Company’s outstanding 8.5% , 6.0% and 7.0% convertible perpetual preferred stock covering 90.1 million shares for the year ended December 31, 2013 were excluded from the computation of loss per share because their effect would have been antidilutive under the if-converted method. See Note 16 for discussion of the Company’s convertible perpetual preferred stock.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2015
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions The Company entered into transactions in the ordinary course of business with certain related parties. These transactions primarily consisted of sales of oil and natural gas. See Note 10 for accounts payable attributable to related party transactions. During the year ended December 31, 2013 sales to related parties were $1.6 million . This amount primarily related to sales of natural gas from the Permian Properties, which were sold in February 2013, to the Company’s partner in GRLP. Former Chairman and CEO Severance. On June 28, 2013, the Company’s then current CEO, Tom Ward, separated employment from the Company. In accordance with the terms of Mr. Ward’s employment agreement, the Company incurred $ 57.9 million in salary and bonus expense and $36.8 million associated with the accelerated vesting of approximately 6.3 million shares of restricted stock awards during the third quarter of 2013. As of December 31, 2015 , the remaining amount due under the terms of his employment agreement include $1.5 million to be paid in monthly installments through December 2016. This amount is included in other current liabilities in the accompanying consolidated balance sheet. See Note 16 for discussion of the stockholder receivable due from Mr. Ward. Other Employee Termination Benefits. Certain employees received termination benefits, including severance and accelerated stock vesting, upon separation of service from the Company during the years ended December 31, 2015 , 2014 and 2013. For the years ended December 31, 2015 and 2014, employee termination benefits were $12.5 million and $8.9 million , respectively, primarily as a result of a reduction in workforce and executives’ separation from employment, and the sale of the Gulf Properties. For the year ended December 31, 2013, employee termination benefits, excluding amounts attributable to the Company’s former chairman and CEO, were $23.2 million , primarily as a result of other executives’ separation from employment. Oklahoma City Thunder Agreements. Until April 2014, the Company’s former Chairman and CEO owned, and one of the Company’s directors currently owns, minority interests in a limited liability company that owns and operates the Oklahoma City Thunder basketball team. The Company was party to a sponsorship agreement, whereby it paid approximately $3.3 million per year for advertising and promotional activities related to the Oklahoma City Thunder, which terminated with the conclusion of the 2012-2013 season. Office Lease. The Company is party to a commercial lease to rent space in a building owned by an entity that is partially owned by one of the Company’s directors. The terms provide for a lease term through December 2017 with annual rent of approximately $0.5 million . Any renovation costs paid by the Company with respect to the leased space are applied toward future rent payments. As of December 31, 2015 , the Company has made renovations costing approximately $3.3 million . 2014 Divestiture. See Note 3 for discussion of the sale of the Gulf Properties to Fieldwood and the Company’s guarantee on behalf of Fieldwood of certain associated plugging and abandonment obligations associated with the Gulf Properties. Fieldwood is a portfolio company of Riverstone Holdings LLC, affiliates of which own a significant number of shares of the Company’s common stock. Acquisition of Ownership Interest. In March 2014, the Company purchased the additional ownership interest owned by its partner in GRLP and Genpar, which was deemed a related party at the time. See Note 4 for additional discussion.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2015
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Royalty Trust Distributions . On January 28, 2016 , the Royalty Trusts announced quarterly distributions for the three-month period ended December 31, 2015 . The following distributions will be paid on February 26, 2016 to holders of record as of the close of business on February 12, 2016 (in thousands): Royalty Trust Total Distribution Amount to be Distributed to Third-Party Unitholders Mississippian Trust I $ 8,708 $ 6,367 Permian Trust 7,560 7,560 Mississippian Trust II 6,825 5,682 Total $ 23,093 $ 19,609 Preferred Stock Dividends. In January 2016, the Company announced the suspension of payment of the semi-annual dividend on shares of its 8.5% convertible perpetual preferred stock. Performance Incentive Plan. In January 2016, the Company implemented a performance incentive plan. The plan is intended to replace, on a prospective basis, the Company’s annual incentive plan and equity-based long-term incentive awards, such as restricted stock awards and restricted stock units, and provides for quarterly cash payments to participants based upon corporate performance goals with payout percentages ranging from 0% to 200% . Personnel Reductions and Severance. The Company discontinued substantially all remaining drilling and oilfield services operations in January 2016 and completed a reduction in its corporate workforce in February 2016. Estimated severance costs incurred associated with these events totaled approximately $17.4 million through February 2016. Senior Credit Facility. In January 2016, the Company borrowed the available capacity under the senior credit facility, or $488.9 million . On March 11, 2016, the administrative agent notified the Company that the lenders had elected to reduce the borrowing base to $340.0 million from $500.0 million pursuant to a special redetermination. On March 21, 2016, the Company notified the administrative agent that the Company would submit for the administrative agent’s consideration proposed additional oil and gas properties to serve as collateral under the senior credit facility sufficient to support a borrowing base of $500.0 million . Additionally, the Company notified the administrative agent that it believed the currently pledged assets are sufficient to support a borrowing base of $500.0 million and reserved the right to exercise all other options available to remedy the borrowing base deficiency, if any. The Company has until April 20, 2016 to submit such additional properties. As discussed further in Note 1 , the report of the Company’s independent registered public accounting firm that accompanies these consolidated financial statements for the year ended December 31, 2015 contains an explanatory paragraph regarding the substantial doubt about the Company’s ability to continue as a going concern, which under the terms of the senior credit facility may result in an event of default. If the Company does not obtain a waiver of this requirement or otherwise cure this event within 30 calendar days of the issuance of these consolidated financial statements, the lenders under the senior credit facility will be able to accelerate the maturity of the debt. Any acceleration of the obligations under the senior credit facility would result in a cross-default and potential acceleration of the Company’s other outstanding long-term debt. Divestiture of WTO Properties and Release from Treating Agreement. On January 21, 2016, the Company paid $11.0 million in cash and transferred ownership of substantially all of its oil and natural gas properties and midstream assets located in the Piñon field in the WTO, including the PGC assets acquired in October 2015, to Occidental and was released from all past, current and future claims and obligations under an existing 30 years treating agreement between the companies. As of December 31, 2015, the Company had accrued approximately $109.9 million for penalties associated with shortfalls in meeting its delivery requirements under the agreement since it became effective in late 2012, including $34.9 million incurred for the year ended December 31, 2015. The Company expects to recognize a loss on the termination of the treating agreement and the cease-use of transportation agreements that support production from the Piñon field, however, is currently obtaining further information needed to evaluate the commitments extinguished and consideration conveyed in the transaction. Production, proved reserves, revenues and direct operating expenses for the oil and natural gas properties transferred in the transaction were 1.9 MMBoe, 24.6 MMBoe, $14.6 million and $41.1 million , respectively, as of and for the year ended December 31, 2015. Interest Payments on Long-Term Debt. On February 16, 2016, the Company elected to defer interest payments then due with respect to its 7.5% Senior Notes due 2023 and its Senior Convertible Notes due 2023 (collectively, the “2023 Notes”). On March 15, 2016, the Company made a payment of approximately $22 million in satisfaction of its obligations under the 2023 Notes. Further, on March 16, 2016, the Company made approximately $28.4 million in interest payments then due with respect to its 7.5% Senior Notes due 2021. Conversions of Long-Term debt to Common Stock. During the period from January 1, 2016 to March 20, 2016, holders of $200.5 million aggregate principal amount of 8.125% Convertible Senior Notes due 2022 and $31.6 million aggregate principal amount of 7.5% Convertible Senior Notes due 2023 exercised conversion options applicable to those notes, resulting in the issuance of approximately 84.4 million shares of Company common stock and aggregate cash payments of $33.5 million for accrued interest and early conversion payments.

Business Segment Information

Business Segment Information	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Business Segment Information	Business Segment Information During the years ended December 31, 2015 , 2014 and 2013 , the Company had three reportable business segments: exploration and production, drilling and oilfield services and midstream services. These segments represent the Company’s three main business units, each offering different products and services. The exploration and production segment is engaged in the exploration and production of oil and natural gas properties and includes the activities of the Royalty Trusts. The drilling and oilfield services segment is engaged in the contract drilling of oil and natural gas wells and provides various oilfield services. The midstream services segment is engaged in the purchasing, gathering, treating and selling of natural gas and coordinates the delivery of electricity to the Company’s exploration and production operations in the Mid-Continent. The All Other column in the tables below includes items not related to the Company’s reportable segments, including the Company’s corporate operations. As discussed in Note 22 , the Company discontinued the substantial majority of activity within its drilling and oilfield services segment in January 2016. The Company is currently evaluating the impact of this event on its segment reporting for periods within the year ending December 31, 2016. Management evaluates the performance of the Company’s business segments based on (loss) income from operations. Summarized financial information concerning the Company’s segments is shown in the following table (in thousands): Exploration and Production(1) Drilling and Oil Field Services(2) Midstream Services(3) All Other(4) Consolidated Total Year Ended December 31, 2015 Revenues $ 707,446 $ 67,358 $ 81,083 $ 5,342 $ 861,229 Inter-segment revenue (12 ) (45,234 ) (47,274 ) — (92,520 ) Total revenues $ 707,434 $ 22,124 $ 33,809 $ 5,342 $ 768,709 Loss from operations $ (4,461,907 ) $ (59,999 ) $ (15,218 ) $ (105,554 ) $ (4,642,678 ) Interest expense, net (42 ) — — (321,379 ) (321,421 ) Gain on extinguishment of debt — — — 641,131 641,131 Other income, net 1,368 13 253 406 2,040 Loss before income taxes $ (4,460,581 ) $ (59,986 ) $ (14,965 ) $ 214,604 $ (4,320,928 ) Capital expenditures(5) $ 656,022 $ 4,632 $ 21,556 $ 19,405 $ 701,615 Depreciation, depletion, amortization and accretion $ 324,471 $ 17,438 $ 11,742 $ 18,121 $ 371,772 At December 31, 2015 Total assets $ 1,959,975 $ 27,621 $ 254,212 $ 749,347 $ 2,991,155 Year Ended December 31, 2014 Revenues $ 1,423,073 $ 192,944 $ 142,987 $ 4,376 $ 1,763,380 Inter-segment revenue (173 ) (116,856 ) (87,593 ) — (204,622 ) Total revenues $ 1,422,900 $ 76,088 $ 55,394 $ 4,376 $ 1,558,758 Income (loss) from operations $ 713,716 $ (37,564 ) $ (9,094 ) $ (76,834 ) $ 590,224 Interest income (expense), net 100 — — (244,209 ) (244,109 ) Other (expense) income, net (423 ) (541 ) 9 4,445 3,490 Income (loss) before income taxes $ 713,393 $ (38,105 ) $ (9,085 ) $ (316,598 ) $ 349,605 Capital expenditures(5) $ 1,508,100 $ 18,385 $ 44,606 $ 37,798 $ 1,608,889 Depreciation, depletion, amortization and accretion $ 443,573 $ 29,105 $ 10,085 $ 20,260 $ 503,023 At December 31, 2014 Total assets $ 6,273,802 $ 115,083 $ 219,691 $ 650,649 $ 7,259,225 Year Ended December 31, 2013 Revenues $ 1,834,480 $ 187,456 $ 179,989 $ 3,127 $ 2,205,052 Inter-segment revenue (320 ) (120,815 ) (100,529 ) — (221,664 ) Total revenues $ 1,834,160 $ 66,641 $ 79,460 $ 3,127 $ 1,983,388 Income (loss) from operations $ 62,509 $ (40,155 ) $ (21,567 ) $ (169,788 ) $ (169,001 ) Interest income (expense), net 1,168 — (209 ) (271,193 ) (270,234 ) Loss on extinguishment of debt — — — (82,005 ) (82,005 ) Other income (expense), net 5,487 — (3,222 ) 10,180 12,445 Income (loss) before income taxes $ 69,164 $ (40,155 ) $ (24,998 ) $ (512,806 ) $ (508,795 ) Capital expenditures(5) $ 1,319,012 $ 7,125 $ 55,706 $ 42,040 $ 1,423,883 Depreciation, depletion, amortization and accretion $ 605,242 $ 33,291 $ 7,972 $ 20,140 $ 666,645 ____________________ (1) (Loss) income from operations includes full cost ceiling limitation impairments of $4.5 billion and $164.8 million for the years ended December 31, 2015 and 2014 , respectively, a loss on the sale of the Permian Properties of $398.9 million for the year ended December 31, 2013 and the Company’s (gain) loss on derivative contracts, including net cash payments upon settlement, for the years ended December 31, 2015 , 2014 and 2013 . See Note 13 for discussion of derivative contracts. (2) For the years ended December 31, 2015 , 2014 and 2013 , (loss) income from operations includes impairments of $37.6 million , $27.4 million , and $11.1 million , respectively, on certain drilling assets. (3) For the years ended December 31, 2015 , 2014 and 2013 , (loss) income from operations includes impairments of other midstream assets and the Company’s gas treating plants in west Texas of $7.1 million , $0.6 million and $3.9 million , respectively. (4) (Loss) income from operations for the year ended December 31, 2015 includes an impairment of $15.4 million on property located in downtown Oklahoma City, Oklahoma and $0.7 million on gathering and compression equipment. See Note 7 . For the year ended December 31, 2013, (loss) income from operations includes a $2.9 million impairment of a corporate asset and an $8.3 million impairment of the Company’s CO 2 compression facilities. (5) On an accrual basis and exclusive of acquisitions. Major Customers. For the years ended December 31, 2015 , 2014 and 2013 , the Company had sales exceeding 10% of total revenues to the following oil and natural gas purchasers (in thousands): 2015 Sales % of Revenue Plains Marketing, L.P. $ 318,018 41.4 % Targa Pipeline Mid-Continent West OK LLC $ 231,649 30.1 % 2014 Sales % of Revenue Plains Marketing, L.P. $ 597,117 38.3 % Targa Pipeline Mid-Continent West OK LLC $ 333,027 21.4 % 2013 Sales % of Revenue Plains Marketing, L.P. $ 491,258 24.8 % Shell Trading (US) Company $ 347,422 17.5 % Targa Pipeline Mid-Continent West OK LLC $ 211,838 10.7 % Plains Marketing, L.P., Targa Pipeline Mid-Continent West OK LLC (formerly Atlas Pipeline Mid-Continent West OK LLC) and Shell Trading (US) Company are purchasers of oil, natural gas and NGLs sold by the Company’s exploration and production segment.

Condensed Consolidating Financi

Condensed Consolidating Financial Information	12 Months Ended
	Dec. 31, 2015
Condensed Consolidating Financial Statements Disclosure [Abstract]
Condensed Consolidating Financial Information	Condensed Consolidating Financial Information The Company provides condensed consolidating financial information for its subsidiaries that are guarantors of its registered debt. As of December 31, 2015 , the subsidiary guarantors, which are 100% owned by the Company, have jointly and severally guaranteed, on a full, unconditional and unsecured basis, the Company’s outstanding Senior Unsecured Notes. The subsidiary guarantees (i) rank equally in right of payment with all of the existing and future senior debt of the subsidiary guarantors; (ii) rank senior to all of the existing and future subordinated debt of the subsidiary guarantors; (iii) are effectively subordinated in right of payment to any existing or future secured obligations of the subsidiary guarantors to the extent of the value of the assets securing such obligations; (iv) are structurally subordinated to all debt and other obligations of the subsidiaries of the guarantors who are not themselves subsidiary guarantors; and (v) are only released under certain customary circumstances. The Company’s subsidiary guarantors guarantee payments of principal and interest under the Company’s registered notes. Certain of the Company’s wholly owned subsidiaries that were sold in February 2014, as discussed in Note 3 , guaranteed the Company’s registered debt. Upon the closing of the sale, these subsidiaries were released from their guarantees. The condensed consolidating financial information in the tables below reflects these subsidiaries’ financial information through the date of the sale. The following condensed consolidating financial information represents the financial information of SandRidge Energy, Inc., its wholly owned subsidiary guarantors and its non-guarantor subsidiaries, prepared on the equity basis of accounting. The non-guarantor subsidiaries, including consolidated VIEs, majority owned subsidiaries and certain immaterial wholly owned subsidiaries, are included in the non-guarantors column in the tables below. The financial information may not necessarily be indicative of the financial position, results of operations or cash flows had the subsidiary guarantors operated as independent entities. Condensed Consolidating Balance Sheets December 31, 2015 Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) ASSETS Current assets Cash and cash equivalents $ 426,917 $ 847 $ 7,824 $ — $ 435,588 Accounts receivable, net — 122,606 4,781 — 127,387 Intercompany accounts receivable 1,226,994 1,305,573 30,683 (2,563,250 ) — Derivative contracts — 84,349 — — 84,349 Prepaid expenses — 6,826 7 — 6,833 Other current assets — 19,931 — — 19,931 Total current assets 1,653,911 1,540,132 43,295 (2,563,250 ) 674,088 Property, plant and equipment, net — 2,124,532 110,170 — 2,234,702 Investment in subsidiaries 2,749,514 8,531 — (2,758,045 ) — Other assets 72,259 16,008 — (5,902 ) 82,365 Total assets $ 4,475,684 $ 3,689,203 $ 153,465 $ (5,327,197 ) $ 2,991,155 LIABILITIES AND STOCKHOLDERS’ (DEFICIT) EQUITY Current liabilities Accounts payable and accrued expenses $ 160,122 $ 265,767 $ 2,528 $ — $ 428,417 Intercompany accounts payable 1,337,688 1,192,569 32,993 (2,563,250 ) — Derivative contracts — 573 — — 573 Asset retirement obligations — 8,399 — — 8,399 Total current liabilities 1,497,810 1,467,308 35,521 (2,563,250 ) 437,389 Investment in subsidiaries 1,038,303 400,771 — (1,439,074 ) — Long-term debt 3,637,408 — — (5,902 ) 3,631,506 Asset retirement obligations — 95,179 — — 95,179 Other long-term obligations 80 14,734 — — 14,814 Total liabilities 6,173,601 1,977,992 35,521 (4,008,226 ) 4,178,888 Stockholders’ (Deficit) Equity SandRidge Energy, Inc. stockholders’ (deficit) equity (1,697,917 ) 1,711,211 117,944 (1,829,155 ) (1,697,917 ) Noncontrolling interest — — — 510,184 510,184 Total stockholders’ (deficit) equity (1,697,917 ) 1,711,211 117,944 (1,318,971 ) (1,187,733 ) Total liabilities and stockholders’ (deficit) equity $ 4,475,684 $ 3,689,203 $ 153,465 $ (5,327,197 ) $ 2,991,155 December 31, 2014 Parent(1) Guarantors(1)(2) Non-Guarantors(3) Eliminations(2)(3) Consolidated (In thousands) ASSETS Current assets Cash and cash equivalents $ 170,468 $ 1,398 $ 9,387 $ — $ 181,253 Accounts receivable, net 7 299,764 30,313 (7 ) 330,077 Intercompany accounts receivable 751,376 1,339,152 41,679 (2,132,207 ) — Derivative contracts — 284,825 45,043 (38,454 ) 291,414 Prepaid expenses — 7,971 10 — 7,981 Other current assets — 21,193 — — 21,193 Total current assets 921,851 1,954,303 126,432 (2,170,668 ) 831,918 Property, plant and equipment, net — 5,137,702 1,077,355 — 6,215,057 Investment in subsidiaries 6,606,198 25,944 — (6,632,142 ) — Derivative contracts — 47,003 — — 47,003 Other assets 152,286 18,197 666 (5,902 ) 165,247 Total assets $ 7,680,335 $ 7,183,149 $ 1,204,453 $ (8,808,712 ) $ 7,259,225 LIABILITIES AND EQUITY Current liabilities Accounts payable and accrued expenses $ 151,825 $ 526,941 $ 4,633 $ (7 ) $ 683,392 Intercompany accounts payable 1,365,210 731,103 35,894 (2,132,207 ) — Derivative contracts — 38,454 — (38,454 ) — Deferred tax liability 95,843 — — — 95,843 Other current liabilities — 5,216 — — 5,216 Total current liabilities 1,612,878 1,301,714 40,527 (2,170,668 ) 784,451 Investment in subsidiaries 928,217 134,013 — (1,062,230 ) — Long-term debt 3,201,338 — — (5,902 ) 3,195,436 Asset retirement obligations — 54,402 — — 54,402 Other long-term obligations 77 15,039 — — 15,116 Total liabilities 5,742,510 1,505,168 40,527 (3,238,800 ) 4,049,405 Equity SandRidge Energy, Inc. stockholders’ equity 1,937,825 5,677,981 1,163,926 (6,841,907 ) 1,937,825 Noncontrolling interest — — — 1,271,995 1,271,995 Total equity 1,937,825 5,677,981 1,163,926 (5,569,912 ) 3,209,820 Total liabilities and equity $ 7,680,335 $ 7,183,149 $ 1,204,453 $ (8,808,712 ) $ 7,259,225 ____________________ (1) Parent accounts payable and accrued expenses have decreased and intercompany accounts payable have increased by approximately $49.5 million for amounts previously misclassified. Guarantor accounts payable and accrued expenses have increased and intercompany accounts payable have decreased by a corresponding amount. (2) Amounts presented as property, plant and equipment have been revised to include approximately $150.4 million previously misclassified as investment in subsidiary. (3) Amounts previously misclassified as property, plant and equipment and SandRidge Energy, Inc. stockholders’ equity totaling approximately $150.4 million are now presented as Guarantor property, plant and equipment. Condensed Consolidating Statements of Operations Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Year Ended December 31, 2015 Total revenues $ — $ 682,778 $ 85,939 $ (8 ) $ 768,709 Expenses Direct operating expenses — 364,483 10,879 (8 ) 375,354 General and administrative 213 145,796 4,157 — 150,166 Depreciation, depletion, amortization and accretion — 339,647 32,125 — 371,772 Impairment — 3,599,810 934,879 — 4,534,689 Gain on derivative contracts — (65,049 ) (8,012 ) — (73,061 ) Loss on settlement of contract — 50,976 — — 50,976 Loss (gain) on sale of assets — 2,217 (726 ) — 1,491 Total expenses 213 4,437,880 973,302 (8 ) 5,411,387 Loss from operations (213 ) (3,755,102 ) (887,363 ) — (4,642,678 ) Equity earnings from subsidiaries (4,017,082 ) (263,847 ) — 4,280,929 — Interest expense, net (321,378 ) (43 ) — — (321,421 ) Gain on extinguishment of debt 641,131 — — — 641,131 Other income, net — 1,910 130 — 2,040 Loss before income taxes (3,697,542 ) (4,017,082 ) (887,233 ) 4,280,929 (4,320,928 ) Income tax expense 3 — 120 — 123 Net loss (3,697,545 ) (4,017,082 ) (887,353 ) 4,280,929 (4,321,051 ) Less: net loss attributable to noncontrolling interest — — — (623,506 ) (623,506 ) Net loss attributable to SandRidge Energy, Inc. $ (3,697,545 ) $ (4,017,082 ) $ (887,353 ) $ 4,904,435 $ (3,697,545 ) Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Year Ended December 31, 2014 Total revenues $ — $ 1,341,531 $ 217,367 $ (140 ) $ 1,558,758 Expenses Direct operating expenses — 467,175 16,854 (140 ) 483,889 General and administrative 331 118,249 4,285 — 122,865 Depreciation, depletion, amortization and accretion — 446,149 56,874 — 503,023 Impairment — 150,125 42,643 — 192,768 Gain on derivative contracts — (292,733 ) (41,278 ) — (334,011 ) Total expenses 331 888,965 79,378 (140 ) 968,534 (Loss) income from operations (331 ) 452,566 137,989 — 590,224 Equity earnings from subsidiaries 495,154 38,967 — (534,121 ) — Interest (expense) income, net (244,209 ) 100 — — (244,109 ) Other income (expense), net — 3,521 (31 ) — 3,490 Income before income taxes 250,614 495,154 137,958 (534,121 ) 349,605 Income tax (benefit) expense (2,671 ) — 378 — (2,293 ) Net income 253,285 495,154 137,580 (534,121 ) 351,898 Less: net income attributable to noncontrolling interest — — — 98,613 98,613 Net income attributable to SandRidge Energy, Inc. $ 253,285 $ 495,154 $ 137,580 $ (632,734 ) $ 253,285 Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Year Ended December 31, 2013 Total revenues $ — $ 1,675,481 $ 308,300 $ (393 ) $ 1,983,388 Expenses Direct operating expenses — 654,080 29,143 (393 ) 682,830 General and administrative 329 323,808 6,288 — 330,425 Depreciation, depletion, amortization and accretion — 581,435 85,210 — 666,645 Impairment — 15,038 11,242 — 26,280 Loss on derivative contracts — 24,702 22,421 — 47,123 Loss on sale of assets — 291,743 107,343 — 399,086 Total expenses 329 1,890,806 261,647 (393 ) 2,152,389 (Loss) income from operations (329 ) (215,325 ) 46,653 — (169,001 ) Equity earnings from subsidiaries (195,118 ) 3,075 — 192,043 — Interest (expense) income, net (271,193 ) 959 — — (270,234 ) Loss on extinguishment of debt (82,005 ) — — — (82,005 ) Other income (expense), net — 16,173 (3,728 ) — 12,445 (Loss) income before income taxes (548,645 ) (195,118 ) 42,925 192,043 (508,795 ) Income tax expense 5,244 — 440 — 5,684 Net (loss) income (553,889 ) (195,118 ) 42,485 192,043 (514,479 ) Less: net income attributable to noncontrolling interest — — — 39,410 39,410 Net (loss) income attributable to SandRidge Energy, Inc. $ (553,889 ) $ (195,118 ) $ 42,485 $ 152,633 $ (553,889 ) Condensed Consolidating Statements of Cash Flows Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Year Ended December 31, 2015 Net cash (used in) provided by operating activities $ (326,674 ) $ 524,313 $ 124,626 $ 51,272 $ 373,537 Cash flows from investing activities Capital expenditures for property, plant and equipment — (879,201 ) — — (879,201 ) Acquisition of assets — (216,943 ) — — (216,943 ) Other — 74,140 907 (18,543 ) 56,504 Net cash (used in) provided by investing activities — (1,022,004 ) 907 (18,543 ) (1,039,640 ) Cash flows from financing activities Proceeds from borrowings 2,065,000 — — — 2,065,000 Repayments of borrowings (939,466 ) — — — (939,466 ) Distributions to unitholders — — (158,629 ) 20,324 (138,305 ) Intercompany (advances) borrowings, net (475,618 ) 497,140 (21,522 ) — — Other (66,793 ) — 53,055 (53,053 ) (66,791 ) Net cash provided by (used in) financing activities 583,123 497,140 (127,096 ) (32,729 ) 920,438 Net increase (decrease) in cash and cash equivalents 256,449 (551 ) (1,563 ) — 254,335 Cash and cash equivalents at beginning of year 170,468 1,398 9,387 — 181,253 Cash and cash equivalents at end of year $ 426,917 $ 847 $ 7,824 $ — $ 435,588 Parent(1) Guarantors(1)(2) Non-Guarantors Eliminations(2) Consolidated (In thousands) Year Ended December 31, 2014 Net cash (used in) provided by operating activities $ (240,932 ) $ 641,181 $ 212,427 $ 8,438 $ 621,114 Cash flows from investing activities Capital expenditures for property, plant and equipment — (1,553,332 ) — — (1,553,332 ) Proceeds from sale of assets — 711,728 2,747 — 714,475 Other — 28,256 1,140 (47,780 ) (18,384 ) Net cash (used in) provided by investing activities — (813,348 ) 3,887 (47,780 ) (857,241 ) Cash flows from financing activities Distributions to unitholders — — (234,327 ) 40,520 (193,807 ) Repurchase of common stock (111,827 ) — — — (111,827 ) Intercompany (advances) borrowings, net (215,368 ) 215,373 (5 ) — — Other (66,910 ) (42,821 ) 19,260 (1,178 ) (91,649 ) Net cash (used in) provided by financing activities (394,105 ) 172,552 (215,072 ) 39,342 (397,283 ) Net (decrease) increase in cash and cash equivalents (635,037 ) 385 1,242 — (633,410 ) Cash and cash equivalents at beginning of year 805,505 1,013 8,145 — 814,663 Cash and cash equivalents at end of year $ 170,468 $ 1,398 $ 9,387 $ — $ 181,253 ____________________ (1) Net cash (used in) provided by operating activities for the Parent has decreased to correctly exclude $382.7 million in intercompany transactions, with a corresponding increase for Guarantors for this same line item. In addition, Intercompany (advances) borrowings, net for the Parent has increased to correctly include approximately $382.7 million of intercompany transactions, with a corresponding decrease for Guarantors for the same line item. The corrections did not result in any changes to consolidated net cash provided by operating activities or net cash used in financing activities. (2) Other investing activities for the Guarantor has increased to correctly exclude $193.8 million in noncontrolling interest distributions, with a corresponding decrease for Eliminations for this same line item. In addition, other financing activities for the Guarantor, has decreased to correctly exclude $193.8 million of noncontrolling interest distributions, with a corresponding increase for Eliminations for the same line item. The corrections did not result in any changes to consolidated net cash (used in) provided by investing activities or net cash used in financing activities. Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Year Ended December 31, 2013 Net cash (used in) provided by operating activities $ (239,026 ) $ 852,026 $ 254,723 $ 907 $ 868,630 Cash flows from investing activities Capital expenditures for property, plant and equipment — (1,496,731 ) — — (1,496,731 ) Proceeds from sale of assets — 2,566,742 17,373 — 2,584,115 Other — 89,606 3,197 (109,831 ) (17,028 ) Net cash used in investing activities — 1,159,617 20,570 (109,831 ) 1,070,356 Cash flows from financing activities Repayments of borrowings (1,115,500 ) — — — (1,115,500 ) Premium on debt redemption (61,997 ) — — — (61,997 ) Distributions to unitholders — — (299,675 ) 93,205 (206,470 ) Dividends paid—preferred (55,525 ) — — — (55,525 ) Intercompany borrowings (advances) , net 2,009,146 (2,018,212 ) 9,066 — — Other (31,821 ) 6,660 14,845 15,719 5,403 Net cash provided by (used in) financing activities 744,303 (2,011,552 ) (275,764 ) 108,924 (1,434,089 ) Net increase (decrease) in cash and cash equivalents 505,277 91 (471 ) — 504,897 Cash and cash equivalents at beginning of year 300,228 922 8,616 — 309,766 Cash and cash equivalents at end of year $ 805,505 $ 1,013 $ 8,145 $ — $ 814,663

Supplemental Information on Oil

Supplemental Information on Oil and Natural Gas Producing Activities	12 Months Ended
	Dec. 31, 2015
Extractive Industries [Abstract]
Supplemental Information on Oil and Natural Gas Producing Activities	Supplemental Information on Oil and Natural Gas Producing Activities The supplemental information includes capitalized costs related to oil and natural gas producing activities; costs incurred in oil and natural gas property acquisition, exploration and development; and the results of operations for oil and natural gas producing activities. Supplemental information is also provided for oil, natural gas and NGL production and average sales prices; the estimated quantities of proved oil, natural gas and NGL reserves; the standardized measure of discounted future net cash flows associated with proved oil, natural gas and NGL reserves; and a summary of the changes in the standardized measure of discounted future net cash flows associated with proved oil, natural gas and NGL reserves. Capitalized Costs Related to Oil and Natural Gas Producing Activities The Company’s capitalized costs for oil and natural gas activities consisted of the following (in thousands): December 31, 2015 2014 2013 Oil and natural gas properties Proved $ 12,529,681 $ 11,707,147 $ 10,972,816 Unproved 363,149 290,596 531,606 Total oil and natural gas properties 12,892,830 11,997,743 11,504,422 Less accumulated depreciation, depletion and impairment (11,149,888 ) (6,359,149 ) (5,762,969 ) Net oil and natural gas properties capitalized costs $ 1,742,942 $ 5,638,594 $ 5,741,453 Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development Costs incurred in oil and natural gas property acquisition, exploration and development activities which have been capitalized are summarized as follows (in thousands): Year Ended December 31, 2015 2014 2013 Acquisitions of properties Proved $ 35,376 $ 73,370 $ 21,130 Unproved 210,065 123,649 100,242 Exploration(1) 29,297 41,070 82,775 Development 571,562 1,288,395 1,131,269 Total cost incurred $ 846,300 $ 1,526,484 $ 1,335,416 ____________________ (1) Includes seismic costs of $7.1 million , $10.8 million and $6.7 million for 2015 , 2014 and 2013 , respectively. Results of Operations for Oil and Natural Gas Producing Activities (Unaudited) The Company’s results of operations from oil and natural gas producing activities for each of the years 2015 , 2014 and 2013 are shown in the following table (in thousands): Year Ended December 31, 2015 2014(1) 2013 Revenues $ 707,434 $ 1,420,879 $ 1,820,278 Expenses Production costs 324,141 377,819 548,719 Depreciation and depletion 319,913 434,295 567,732 Accretion of asset retirement obligations 4,477 9,092 36,777 Impairment 4,473,787 164,779 — Total expenses 5,122,318 985,985 1,153,228 (Loss) income before income taxes (4,414,884 ) 434,894 667,050 Income tax expense (benefit)(2) 126 (2,852 ) (7,471 ) Results of operations for oil and natural gas producing activities (excluding corporate overhead and interest costs) $ (4,415,010 ) $ 437,746 $ 674,521 ____________________ (1) Total expenses increased by $164.8 million and benefit of income taxes decreased by $1.1 million to correctly include the impact of the ceiling test impairment incurred during the year ended December 31, 2014. (2) Reflects the Company’s effective tax rate for each period. Oil, Natural Gas and NGL Reserve Quantities (Unaudited) Proved oil, natural gas and NGL reserves are those quantities, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible, based on prices used to estimate reserves, from a given date forward from known reservoirs, and under existing economic conditions, operating methods, and government regulation prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain. The term “reasonable certainty” implies a high degree of confidence that the quantities of oil, natural gas and NGLs actually recovered will equal or exceed the estimate. To achieve reasonable certainty, the Company’s engineers and independent petroleum consultants relied on technologies that have been demonstrated to yield results with consistency and repeatability. The technologies and economic data used to estimate the Company’s proved reserves include, but are not limited to, well logs, geologic maps, seismic data, well test data, production data, historical price and cost information and property ownership interests. The accuracy of the reserve estimates is dependent on many factors, including the following: • the quality and quantity of available data and the engineering and geological interpretation of that data; • estimates regarding the amount and timing of future costs, which could vary considerably from actual costs; • the accuracy of mandated economic assumptions such as the future prices of oil, natural gas and NGLs; and • the judgment of the personnel preparing the estimates. Proved developed reserves are proved reserves expected to be recovered through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared with the cost of a new well. Proved undeveloped reserves are reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively large major expenditure is required for recompletion. The table below represents the Company’s estimate of proved oil, natural gas and NGL reserves attributable to the Company’s net interest in oil and natural gas properties, all of which are located in the continental United States, based upon the evaluation by the Company and its independent petroleum engineers of pertinent geoscience and engineering data in accordance with the SEC’s regulations. Estimates of the substantial majority of the Company’s proved reserves have been prepared by independent reservoir engineers and geoscience professionals and are reviewed by members of the Company’s senior management with professional training in petroleum engineering to ensure that the Company consistently applies rigorous professional standards and the reserve definitions prescribed by the SEC. Cawley, Gillespie & Associates, Inc. (“CG&A”), Ryder Scott Company, L.P. (“Ryder Scott”) and Netherland, Sewell & Associates, Inc. (“Netherland Sewell”), independent oil and natural gas consultants, prepared the estimates of proved reserves of oil, natural gas and NGLs attributable to the majority of the Company’s net interest in oil and natural gas properties as of the end of one or more of 2015 , 2014 and 2013 . CG&A, Ryder Scott and Netherland Sewell are independent petroleum engineers, geologists, geophysicists and petrophysicists and do not own an interest in the Company or its properties and are not employed on a contingent basis. CG&A and Netherland Sewell prepared the estimates of proved reserves for a majority of the Company’s properties as of December 31, 2015 . The remaining 9.9% of estimates of proved reserves was based on Company estimates. The Company believes the geoscience and engineering data examined provides reasonable assurance that the proved reserves are economically producible in future years from known reservoirs, and under existing economic conditions, operating methods and governmental regulations. Estimates of proved reserves are subject to change, either positively or negatively, as additional information is available and contractual and economic conditions change. 2015 Activity. During 2015, the Company recognized additional oil, NGL and natural gas reserves from extensions and discoveries of 9.7 MMBbls, 9.3 MMBbls, and 160.9 Bcf, respectively, primarily due to successful drilling in the Mississippian formation in the Mid-Continent area. Acquisition of the Rockies assets, located in Jackson County, Colorado, in December 2015 added 27.6 MMBoe of reserves. These positive revisions were offset by (i) negative pricing revisions of approximately 54 MMBbls for oil, 36 MMBbls for NGLs and 687 Bcf for natural gas, due primarily to significantly lower commodity prices in 2015, and (ii) negative revisions of approximately 16 MMBbls for oil, 1 MMBbls for NGLs and 74 Bcf for natural gas primarily from well performance in the Mid-Continent. 2014 Activity. During 2014, the Company recognized additional oil, NGL and natural gas reserves from extensions and discoveries of 37.6 MMBbls, 27.5 MMBbls, and 467.2 Bcf, respectively, primarily due to successful drilling in the Mississippian formation in the Mid-Continent area. Revisions of previous estimates decreased oil reserves by 18.7 MMBbls, primarily comprised of (i) approximately 9 MMBbls from Permian Basin proved undeveloped reserves, largely due to removal of drilling locations not expected to be drilled within a five year period, (ii) approximately 8 MMBbls from well performance in the Mid-Continent and (iii) approximately 2 MMBbls from acreage losses or revisions to well interest ownerships. These negative revisions were offset by positive revisions to NGL and gas reserves of 11.1 MMBbls and 167.6 Bcf, respectively, primarily from well performance in the Mid-Continent area. Acquisitions of reserves added 3.5 MMBoe. Sales of proved reserves during 2014 totaled 55.5 MMBoe from the sale of the Gulf Properties. 2013 Activity. The Company sold its Permian Properties in February 2013. Proved reserves were 198.9 MMBoe, 55% of which were proved developed reserves, for the Permian Properties at December 31, 2012. Estimated standardized measure of discounted cash flows for the Permian Properties, determined by allocating the Company's standardized measure of discounted cash flows to the Permian Properties based on the present value of discounted cash flows attributable to the Permian Properties relative to the Company's total present value of discounted cash flows was $2.5 billion . See Note 3 for additional information regarding the sale. The Company recognized an increase of 119.2 MMBoe in total reserves primarily attributable to extensions and discoveries associated with successful drilling in the Mississippian formation in the Mid-Continent. The summary below presents changes in the Company’s estimated reserves for 2013 , 2014 and 2015 . Oil NGL Natural Gas (MBbls) (MBbls) (MMcf)(1) Proved developed and undeveloped reserves As of December 31, 2012 262,045 67,994 1,415,042 Revisions of previous estimates (13,969 ) 3,717 (53,432 ) Acquisitions of new reserves 43 13 363 Extensions and discoveries 40,570 18,686 359,918 Sales of reserves in place (131,769 ) (29,067 ) (228,229 ) Production (14,279 ) (2,291 ) (103,233 ) As of December 31, 2013(2) 142,641 59,052 1,390,429 Revisions of previous estimates (18,687 ) 11,103 167,589 Acquisitions of new reserves 1,009 441 12,527 Extensions and discoveries 37,603 27,500 467,185 Sales of reserves in place (25,659 ) (2,516 ) (163,800 ) Production (10,876 ) (3,794 ) (85,697 ) As of December 31, 2014(2) 126,031 91,786 1,788,233 Revisions of previous estimates (70,708 ) (37,384 ) (759,106 ) Acquisitions of new reserves 22,447 2,460 15,952 Extensions and discoveries 9,741 9,257 160,865 Production (9,600 ) (5,044 ) (92,104 ) As of December 31, 2015(2) 77,911 61,075 1,113,840 Proved developed reserves As of December 31, 2012 136,605 33,785 896,701 As of December 31, 2013 83,893 35,807 951,609 As of December 31, 2014 79,022 56,823 1,203,447 As of December 31, 2015 48,639 51,089 964,617 Proved undeveloped reserves As of December 31, 2012 125,440 34,209 518,341 As of December 31, 2013 58,748 23,245 438,820 As of December 31, 2014 47,009 34,963 584,786 As of December 31, 2015 29,272 9,986 149,223 ____________________ (1) Natural gas reserves are computed at 14.65 pounds per square inch absolute and 60 degrees Fahrenheit. (2) Includes proved reserves attributable to noncontrolling interests at December 31, 2015 , 2014 and 2013 as shown in the table below: December 31, 2015 2014 2013 Oil (MBbl) 7,004 11,027 13,569 NGL (MBbl) 3,694 4,761 4,737 Natural gas (MMcf) 50,508 70,833 69,693 Standardized Measure of Discounted Future Net Cash Flows (Unaudited) The standardized measure of discounted cash flows and summary of the changes in the standardized measure computation from year to year are prepared in accordance with Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas (“ASC Topic 932”). The assumptions underlying the computation of the standardized measure of discounted cash flows may be summarized as follows: • the standardized measure includes the Company’s estimate of proved oil, natural gas and NGL reserves and projected future production volumes based upon economic conditions; • pricing is applied based upon 12-month average market prices at December 31, 2015 , 2014 and 2013 adjusted for fixed or determinable contracts that are in existence at year-end. The calculated weighted average per unit prices for the Company’s proved reserves and future net revenues were as follows: At December 31, 2015 2014 2013 Oil (per barrel) $ 45.29 $ 91.65 $ 95.67 NGL (per barrel) $ 12.68 $ 32.79 $ 31.40 Natural gas (per Mcf) $ 1.87 $ 3.61 $ 3.65 • future development and production costs are determined based upon actual cost at year-end; • the standardized measure includes projections of future abandonment costs based upon actual costs at year-end; and • a discount factor of 10% per year is applied annually to the future net cash flows. The summary below presents the Company’s future net cash flows relating to proved oil, natural gas and NGL reserves based on the standardized measure in ASC Topic 932 (in thousands). At December 31, 2015 2014 2013 Future cash inflows from production $ 6,387,944 $ 21,022,320 $ 19,937,484 Future production costs (2,731,542 ) (6,499,366 ) (6,843,713 ) Future development costs(1) (838,945 ) (1,810,201 ) (2,546,680 ) Future income tax expenses (901 ) (3,223,740 ) (2,283,541 ) Undiscounted future net cash flows 2,816,556 9,489,013 8,263,550 10% annual discount (1,501,994 ) (5,401,261 ) (4,245,939 ) Standardized measure of discounted future net cash flows(2) $ 1,314,562 $ 4,087,752 $ 4,017,611 ____________________ (1) Includes abandonment costs. (2) Includes approximately $224.6 million , $643.3 million and $781.6 million attributable to noncontrolling interests at December 31, 2015 , 2014 and 2013 respectively. The following table represents the Company’s estimate of changes in the standardized measure of discounted future net cash flows from proved reserves (in thousands): Present value as of December 31, 2012 $ 5,840,368 Changes during the year Revenues less production and other costs (1,271,559 ) Net changes in prices, production and other costs 271,566 Development costs incurred 474,275 Net changes in future development costs (207,729 ) Extensions and discoveries 1,406,102 Revisions of previous quantity estimates (296,418 ) Accretion of discount 711,385 Net change in income taxes 477,328 Purchases of reserves in-place 1,628 Sales of reserves in-place (3,172,187 ) Timing differences and other(1) (217,148 ) Net change for the year (1,822,757 ) Present value as of December 31, 2013(2) 4,017,611 Changes during the year Revenues less production and other costs (1,043,060 ) Net changes in prices, production and other costs 331,694 Development costs incurred 364,262 Net changes in future development costs (341,183 ) Extensions and discoveries 1,785,963 Revisions of previous quantity estimates (77,688 ) Accretion of discount 477,458 Net change in income taxes (256,371 ) Purchases of reserves in-place 50,958 Sales of reserves in-place (1,058,330 ) Timing differences and other(1) (163,562 ) Net change for the year 70,141 Present value as of December 31, 2014(2) 4,087,752 Changes during the year Revenues less production and other costs (383,293 ) Net changes in prices, production and other costs (3,813,465 ) Development costs incurred 217,596 Net changes in future development costs 273,437 Extensions and discoveries 230,055 Revisions of previous quantity estimates (1,354,778 ) Accretion of discount 512,483 Net change in income taxes 1,426,333 Purchases of reserves in-place 18,429 Sales of reserves in-place — Timing differences and other(1) 100,013 Net change for the year (2,773,190 ) Present value as of December 31, 2015(2) $ 1,314,562 ____________________ (1) The change in timing differences and other are related to revisions in the Company’s estimated time of production and development. (2) Includes approximately $224.6 million , $643.3 million and $781.6 million attributable to noncontrolling interests at December 31, 2015 , 2014 , and 2013 respectively.

Quarterly Financial Results (Un

Quarterly Financial Results (Unaudited)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Results (Unaudited)	Quarterly Financial Results (Unaudited) The Company’s operating results for each quarter of 2015 and 2014 are summarized below (in thousands, except per share data). First Quarter Second Quarter Third Quarter Fourth Quarter 2015 Total revenues $ 215,308 $ 229,607 $ 180,152 $ 143,642 Loss from operations(1)(2) $ (1,088,456 ) $ (1,535,083 ) $ (1,059,733 ) $ (959,406 ) Net loss(1)(2) $ (1,151,874 ) $ (1,588,731 ) $ (796,485 ) $ (783,961 ) Loss applicable to SandRidge Energy, Inc. common stockholders(1)(2) $ (1,045,834 ) $ (1,375,556 ) $ (649,526 ) $ (664,579 ) Loss applicable per share to SandRidge Energy, Inc. common stockholders(3) Basic $ (2.19 ) $ (2.78 ) $ (1.23 ) $ (1.13 ) Diluted $ (2.19 ) $ (2.78 ) $ (1.23 ) $ (1.13 ) 2014 Total revenues $ 443,056 $ 374,714 $ 394,107 $ 346,881 (Loss) income from operations(4)(5) $ (82,330 ) $ 42,079 $ 256,491 $ 373,984 Net (loss) income(4)(5) $ (142,406 ) $ (17,252 ) $ 197,499 $ 314,057 (Loss applicable) income available to SandRidge Energy, Inc. common stockholders(4)(5) $ (150,217 ) $ (46,775 ) $ 145,957 $ 254,295 (Loss applicable) income available per share to SandRidge Energy, Inc. common stockholders(3) Basic $ (0.31 ) $ (0.10 ) $ 0.30 $ 0.55 Diluted $ (0.31 ) $ (0.10 ) $ 0.27 $ 0.48 ____________________ (1) Includes impairment of $1.1 billion , $1.5 billion , $1.1 billion and $886.8 million for the first, second, third and fourth quarters, respectively. See Note 8 for further discussion of impairment. (2) Includes (gain) loss on derivative contracts of $(49.8) million , $33.0 million , $(42.2) million and $(14.0) million for the first, second, third and fourth quarters, respectively. (3) (Loss applicable) income available per share to common stockholders for each quarter is computed using the weighted-average number of shares outstanding during the quarter, while earnings per share for the fiscal year is computed using the weighted-average number of shares outstanding during the year. Thus, the sum of (loss applicable) income available per share to common stockholders for each of the four quarters may not equal the fiscal year amount. (4) Includes a full cost ceiling limitation impairment of $164.8 million in the first quarter and impairments of drilling assets of $3.1 million and $24.3 million in the second and fourth quarters, respectively. (5) Includes loss (gain) on derivative contracts of $42.5 million , $85.3 million , $(132.6) million and $(329.2) million for the first, second, third and fourth quarters, respectively.

Summary of Significant Accoun33

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Business	Nature of Business. SandRidge Energy, Inc. is an energy company with a principal focus on exploration and production activities in the Mid-Continent region of the United States. The Company owns and operates additional interests in west Texas and the Rockies in Colorado. The Company also operates businesses and infrastructure systems that are complementary to its primary exploration and production activities, including gas gathering and processing facilities, marketing operations, a saltwater gathering and disposal system, an electrical transmission system and a drilling and related oilfield services business.
Principles of Consolidation	Principles of Consolidation. The consolidated financial statements include the accounts of the Company and its wholly owned or majority owned subsidiaries and variable interest entities (“VIEs”) for which the Company is the primary beneficiary. Noncontrolling interest represents third-party ownership interests in the Company’s subsidiaries and consolidated VIEs and is included as a component of equity in the consolidated balance sheets and consolidated statements of changes in equity. All significant intercompany accounts and transactions have been eliminated in consolidation.
Substantial Doubt About Going Concern Disclosure	Going Concern. The Company depends on cash flows from operating activities and, as necessary and available, borrowings under its senior secured revolving credit facility (the “senior credit facility”) to fund its capital expenditures. Additionally, the Company historically has used proceeds from the issuance of equity and debt securities in the capital markets and from sales or other monetizations of assets to fund its capital expenditures. The market price for oil, natural gas and natural gas liquids (“NGLs”) decreased significantly beginning in the fourth quarter of 2014, continuing throughout 2015, and into 2016. The decrease in the market price for production directly reduces the Company’s cash flow from operations and indirectly impacts its other potential sources of funds described above. As discussed in Note 22 , the Company borrowed all of its remaining available capacity under the senior credit facility in January 2016 and in March 2016, the lenders under the senior credit facility elected to reduce the borrowing base to $340.0 million . On March 21, 2016, the Company notified the administrative agent that the Company would submit for the administrative agent’s consideration proposed additional oil and gas properties to serve as collateral under the senior credit facility sufficient to support a borrowing base of $500.0 million . Additionally, the Company notified the administrative agent that it believed the currently pledged assets are sufficient to support a borrowing base of $500.0 million and reserved the right to exercise all other options available to remedy the borrowing base deficiency, if any. The Company has until April 20, 2016 to submit such additional properties. Lower market prices for production may result in further reductions to the borrowing base under the senior credit facility or higher borrowing costs from other potential sources of financing as the Company’s borrowing capacity and borrowing costs are generally related to the value of the Company’s estimated proved reserves. The weakness in pricing may also impact the Company’s ability to negotiate asset monetizations at acceptable prices. As a result of the impacts to the Company’s financial position resulting from declining industry conditions and in consideration of the substantial amount of long-term debt outstanding, the Company has engaged advisors to assist with the evaluation of strategic alternatives, which may include, but not be limited to, seeking a restructuring, amendment or refinancing of existing debt through a private restructuring or reorganization under Chapter 11 of the Bankruptcy Code. However, there can be no assurances that the Company will be able to successfully restructure its indebtedness, improve its financial position or complete any strategic transactions. As a result of these uncertainties and the likelihood of a restructuring or reorganization, management has concluded that there is substantial doubt regarding the Company’s ability to continue as a going concern as it is currently structured. As a result, the report of the Company’s independent registered public accounting firm that accompanies these consolidated financial statements for the year ended December 31, 2015 contains an explanatory paragraph regarding the substantial doubt about the Company’s ability to continue as a going concern, which under the terms of the senior credit facility may result in an event of default. If the Company does not obtain a waiver of this requirement or otherwise cure this event within 30 calendar days of the issuance of these financial statements, the lenders under the senior credit facility will be able to accelerate maturity of the debt. Any acceleration of the obligations under the senior credit facility would result in a cross-default and potential acceleration of the maturity of the Company’s other outstanding long-term debt. These defaults create additional uncertainty associated with the Company’s ability to repay its outstanding long-term debt obligations as they become due and further reinforces the substantial doubt over the Company’s ability to continue as a going concern. The consolidated financial statements have been prepared on a going concern basis of accounting, which contemplates continuity of operations, realization of assets and satisfaction of liabilities and commitments in the normal course of business. The consolidated financial statements do not reflect any adjustments that might result if the Company is unable to continue as a going concern.
Variable Interest Entities	Variable Interest Entities. An entity is referred to as a VIE if it possesses one of the following criteria: (i) it is thinly capitalized, (ii) the residual equity holders do not control the entity, (iii) the equity holders are shielded from economic losses, (iv) the equity holders do not participate fully in the entity’s residual economics, or (v) the entity was established with non-substantive voting interests. The Company consolidates a VIE when it has determined it is the primary beneficiary, which requires significant judgment. The primary beneficiary of a VIE is that variable interest holder possessing a controlling financial interest through (i) its power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and (ii) its obligation to absorb losses or its right to receive benefits from the VIE that could potentially be significant to the VIE. In order to determine whether the Company owns a variable interest in a VIE and the significance of the variable interest, the Company performs a qualitative analysis of the entity’s design, organizational structure, primary decision makers and related financial agreements. In addition to the VIEs that the Company consolidates, until October 2015, the Company also held a variable interest in another VIE that it did not consolidate as it was determined that the Company is not the primary beneficiary. The Company monitors both consolidated and unconsolidated VIEs to determine if any events have occurred that could cause the primary beneficiary to change. See Note 4 for discussion of the Company’s significant associated VIEs.
Reclassifications	Reclassifications. Certain reclassifications have been made to the prior period financial statements to conform to the current period presentation. These reclassifications have no effect on the Company’s previously reported results of operations.
Use of Estimates	Use of Estimates. The preparation of the consolidated financial statements in conformity with accounting principles generally accepted in the United States of America 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 more significant areas requiring the use of assumptions, judgments and estimates include: oil, natural gas and NGL reserves; cash flow estimates used in the valuations of guarantees; impairment tests of long-lived assets; depreciation, depletion and amortization; asset retirement obligations; determinations of significant alterations to the full cost pool and related estimates of fair value used to allocate the full cost pool net book value to divested properties, as necessary; income taxes; valuation of derivative instruments; contingencies; and accrued revenue and related receivables. Although management believes these estimates are reasonable, actual results could differ significantly.
Cash and Cash Equivalents	Cash and Cash Equivalents. The Company considers all highly-liquid instruments with an original maturity of three months or less to be cash equivalents as these instruments are readily convertible to known amounts of cash and bear insignificant risk of changes in value due to their short maturity period.
Accounts Receivable, Net	Accounts Receivable, Net. The Company has receivables for sales of oil, natural gas and NGLs, as well as receivables related to the exploration, production and treating services for oil and natural gas. An allowance for doubtful accounts has been established based on management’s review of the collectability of the receivables in light of historical experience, the nature and volume of the receivables and other subjective factors. Accounts receivable are charged against the allowance, upon approval by management, when they are deemed uncollectible. Refer to Note 6 for further information on the Company’s accounts receivable and allowance for doubtful accounts.
Fair Value of Financial Instruments	Fair Value of Financial Instruments. Certain of the Company’s financial assets and liabilities are measured at fair value. Fair value represents the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. The Company’s financial instruments, not otherwise recorded at fair value, consist primarily of cash, trade receivables, trade payables and long-term debt. The carrying value of cash, trade receivables and trade payables are considered to be representative of their respective fair values due to the short-term maturity of these instruments. See Note 5 for further discussion of the Company’s fair value measurements.
Fair Value of Non-financial Assets and Liabilities	Fair Value of Non-financial Assets and Liabilities. The Company also applies fair value accounting guidance to initially, or as events dictate, measure non-financial assets and liabilities such as those obtained through business acquisitions, property, plant and equipment and asset retirement obligations. These assets and liabilities are subject to fair value adjustments only in certain circumstances and are not subject to recurring revaluations. Fair value may be estimated using comparable market data, a discounted cash flow method, or a combination of the two as considered appropriate based on the circumstances. Under the discounted cash flow method, estimated future cash flows are based on management’s expectations for the future and include estimates of future oil and natural gas production or other applicable sales estimates, operational costs and a risk-adjusted discount rate. The Company may use the present value of estimated future cash inflows and/or outflows or third-party offers or prices of comparable assets with consideration of current market conditions to value its non-financial assets and liabilities when circumstances dictate determining fair value is necessary. Given the significance of the unobservable nature of a number of the inputs, these are considered Level 3 on the fair value hierarchy discussed in Note 5 .
Derivative Financial Instruments	Derivative Financial Instruments. To manage risks related to fluctuations in prices attributable to its expected oil and natural gas production, the Company enters into oil and natural gas derivative contracts. Entrance into such contracts is dependent upon prevailing or anticipated market conditions. The Company may also, from time to time, enter into interest rate swaps in order to manage risk associated with its exposure to variable interest rates. Additionally, the Company has derivatives related to its 8.75% Senior Secured Notes due 2020 (“Senior Secured Notes”) and its 8.125% Convertible Senior Notes due 2022 and 7.5% Convertible Senior Notes due 2023 (collectively, “Convertible Senior Unsecured Notes”) that are recorded at fair value each reporting period. Refer to Notes 5 and 13 for further information on derivatives associated with the Company’s long-term debt. The Company recognizes its derivative instruments as either assets or liabilities at fair value with changes in fair value recognized in earnings unless designated as a hedging instrument with specific hedge accounting criteria having been met. The Company has elected not to designate price risk management activities as accounting hedges under applicable accounting guidance, and, accordingly, accounts for its commodity derivative contracts at fair value with changes in fair value reported currently in earnings. The Company nets derivative assets and liabilities whenever it has a legally enforceable master netting agreement with the counterparty to a derivative contract. The related cash flow impact of the Company’s derivative activities are reflected as cash flows from operating activities unless the derivative contract contains a significant financing element, in which case, cash settlements are classified as cash flows from financing activities in the consolidated statements of cash flows. See Note 13 for further discussion of the Company’s derivatives.
Oil and Natural Gas Operations	Oil and Natural Gas Operations. The Company uses the full cost method to account for its oil and natural gas properties. Under full cost accounting, all costs directly associated with the acquisition, exploration and development of oil, natural gas and NGL reserves are capitalized into a full cost pool. These capitalized costs include costs of unproved properties and internal costs directly related to the Company’s acquisition, exploration and development activities and capitalized interest. The Company capitalized internal costs of $45.1 million , $55.4 million and $74.7 million to the full cost pool during the years ended December 31, 2015 , 2014 and 2013 , respectively. Capitalized costs are amortized using the unit-of-production method. Under this method, depreciation and depletion is computed at the end of each quarter by multiplying total production for the quarter by a depletion rate. The depletion rate is determined by dividing the total unamortized cost base plus future development costs by net equivalent proved reserves at the beginning of the quarter. Costs associated with unproved properties are excluded from the amortizable cost base until a determination has been made as to the existence of proved reserves. Unproved properties are reviewed at the end of each quarter to determine whether the costs incurred should be reclassified to the full cost pool and, thereby, subjected to amortization. The costs associated with unproved properties relate primarily to costs to acquire unproved acreage. Unproved leasehold costs are transferred to the amortization base with the costs of drilling the related well upon determination of the existence of proved reserves or upon impairment of a lease. All items classified as unproved property are assessed, on an individual basis or as a group if properties are individually insignificant, on a quarterly basis for possible impairment or reduction in value. The assessment includes consideration of various factors, including, but not limited to, the following: intent to drill; remaining lease term; geological and geophysical evaluations; drilling results and activity; assignment of proved reserves; and economic viability of development if proved reserves are assigned. During any period in which these factors indicate an impairment, all or a portion of the associated leasehold costs are transferred to the full cost pool and become subject to amortization. Costs of seismic data are allocated to various unproved leaseholds and transferred to the amortization base with the associated leasehold costs on a specific project basis. Under the full cost method of accounting, total capitalized costs of oil and natural gas properties, net of accumulated depreciation, depletion and impairment, less related deferred income taxes may not exceed an amount equal to the present value of future net revenues from proved reserves, discounted at 10% per annum, plus the lower of cost or fair value of unproved properties, plus estimated salvage value, less the related tax effects (the “ceiling limitation”). A ceiling limitation calculation is performed at the end of each quarter. If total capitalized costs, net of accumulated depreciation, depletion and impairment, less related deferred taxes are greater than the ceiling limitation, a write-down or impairment of the full cost pool is required. A write-down of the carrying value of the full cost pool is a non-cash charge that reduces earnings and impacts stockholders’ equity in the period of occurrence and typically results in lower depreciation and depletion expense in future periods. Once incurred, a write-down cannot be reversed at a later date. The ceiling limitation calculation is prepared using the 12-month oil and natural gas average price for the most recent 12 months as of the balance sheet date and as adjusted for basis or location differentials, held constant over the life of the reserves (“net wellhead prices”). If applicable, these net wellhead prices would be further adjusted to include the effects of any fixed price arrangements for the sale of oil and natural gas. Derivative contracts that qualify and are designated as cash flow hedges are included in estimated future cash flows, although the Company historically has not designated any of its derivative contracts as cash flow hedges and has therefore not included its derivative contracts in estimating future cash flows. The future cash outflows associated with future development or abandonment of wells are included in the computation of the discounted present value of future net revenues for purposes of the ceiling limitation calculation. Sales and abandonments of oil and natural gas properties being amortized are accounted for as adjustments to the full cost pool, with no gain or loss recognized, unless the adjustments would significantly alter the relationship between capitalized costs and proved oil, natural gas and NGL reserves. A significant alteration would not ordinarily be expected to occur upon the sale of reserves involving less than 25% of the proved reserve quantities of a cost center.
Property, Plant and Equipment, Net	Property, Plant and Equipment, Net. Other capitalized costs, including drilling equipment, natural gas gathering and treating equipment, transportation equipment and other property and equipment are carried at cost. Renewals and improvements are capitalized while repairs and maintenance are expensed. Depreciation of such property and equipment is computed using the straight-line method over the estimated useful lives of the assets, which range from 10 to 39 years for buildings and 3 to 30 years for equipment. When property and equipment components are disposed of, the cost and the related accumulated depreciation are removed and any resulting gain or loss is reflected in the consolidated statements of operations. Realization of the carrying value of property and equipment is reviewed for possible impairment whenever events or changes in circumstances indicate that the carrying value of such asset may not be recoverable. Assets are considered to be impaired if a forecast of undiscounted estimated future net operating cash flows directly related to the asset or asset group including disposal value, if any, is less than the carrying amount of the asset or asset group. If an asset or asset group is considered to be impaired, the impairment loss is measured as the amount by which the carrying amount of the asset or asset group exceeds its fair value. See Note 8 for further discussion of impairments.
Capitalized Interest	Capitalized Interest. Interest is capitalized on assets being made ready for use using a weighted average interest rate based on the Company’s borrowings outstanding during that time.
Debt Issuance Costs	Debt Issuance Costs. The Company amortizes debt issuance costs related to its long-term debt as interest expense over the scheduled maturity period of the related debt. The Company includes unamortized debt issuance costs in other assets in the consolidated balance sheets. Upon retirement of debt, any unamortized costs are written off and included in the determination of the gain or loss on extinguishment of debt.
Investments	Investments. Investments in marketable equity securities have been designated as available for sale and measured at fair value pursuant to the fair value option which requires unrealized gains and losses be reported in earnings.
Asset Retirement Obligations	Asset Retirement Obligations. The Company owns oil and natural gas properties that require expenditures to plug, abandon and remediate wells at the end of their productive lives, in accordance with applicable federal and state laws. Liabilities for these asset retirement obligations are recorded in the period in which the liability is incurred (at the time the wells are drilled or acquired) at the estimated present value at the asset’s inception, with the offsetting increase to property cost. These property costs are depreciated on a unit-of-production basis within the full cost pool. The liability accretes each period until it is settled or the well is sold, at which time the liability is removed. Both the accretion and the depreciation are included in the consolidated statements of operations. The Company determines its asset retirement obligations by calculating the present value of estimated expenses related to the liability. Estimating future asset retirement obligations requires management to make estimates and judgments regarding timing, existence of a liability and what constitutes adequate restoration. Inherent in the present value calculation rates are the timing of settlement and changes in the legal, regulatory, environmental and political environments, which are subject to change. See Note 14 for further discussion of the Company’s asset retirement obligations.
Revenue Recognition	The Company recognizes revenues and expenses generated from daywork and footage drilling contracts as the services are performed as the Company does not bear the risk of completion of the well. The Company may receive lump-sum fees for the mobilization of equipment and personnel. Mobilization fees received and costs incurred to mobilize a rig from one location to another are recognized at the time mobilization services are performed. In general, natural gas purchased and sold by the midstream business is priced at a published daily or monthly index price. Sales to wholesale customers typically incorporate a premium for managing their transmission and balancing requirements. Midstream services revenues are recognized upon delivery of natural gas to customers and/or when services are rendered, pricing is determined and collectability is reasonably assured. Revenues from third-party midstream services are presented on a gross basis, since the Company acts as a principal by taking ownership of the natural gas purchased and taking responsibility of fulfillment for natural gas volumes sold. Revenue Recognition and Natural Gas Balancing. Sales of oil, natural gas and NGLs are recorded when title of oil, natural gas and NGL production passes to the customer, net of royalties, discounts and allowances, as applicable. Taxes assessed by governmental authorities on oil, natural gas and NGL sales are presented separately from such revenues and included in production tax expense in the consolidated statements of operations.
Natural Gas Balancing	The Company accounts for natural gas production imbalances using the sales method, whereby it recognizes revenue on all natural gas sold to its customers notwithstanding the fact that its ownership may be less than 100% of the natural gas sold. Liabilities are recorded for imbalances greater than the Company’s proportionate share of remaining estimated natural gas reserves. The Company has recorded a liability for natural gas imbalance positions related to natural gas properties with insufficient proved reserves of $1.5 million and $1.4 million at December 31, 2015 and 2014 , respectively. The Company includes the gas imbalance positions in other long-term obligations in the consolidated balance sheets.
Revenue Recognition, Construction Contracts	The Company accounted for its construction contract, discussed in Note 11 , using the completed-contract method, under which contract revenues and costs are recognized when work under the contract is completed or substantially completed and assets have been transferred. In the interim, costs incurred on and billings related to contracts in process are accumulated on the balance sheet. Contract losses are recorded at the time it is determined that a loss will be incurred. Contract gains, if any, are recorded upon substantial completion of the construction project.
Stock-based Compensation	Share-Based Compensation. The Company may grant restricted stock awards to members of its Board of Directors (the “Board”) and its employees. Such awards and the related stock-based compensation cost are measured based on the calculated fair value of the award on the grant date. The expense, net of estimated forfeitures, is recognized on a straight-line basis over the employee’s requisite service period, generally the vesting period of the award. The Company grants restricted stock units to members of the Board and its employees. Such awards are settled in cash, shares of Company common stock or a combination of common stock and cash. Restricted stock units vest over a maximum four -year period from the grant date and are valued based upon the Company’s stock price at each period end. To the extent stock-based compensation cost relates to employees directly involved in exploration and development activities, such amounts are capitalized to oil and natural gas properties. Amounts not capitalized are recognized as general and administrative expense, production expense, cost of sales and midstream and marketing expense in the consolidated statements of operations. The related excess tax benefit received upon vesting of restricted stock, if any, is reflected in the consolidated statements of cash flows as a financing activity. The related excess tax expense due upon vesting of restricted stock, if any, is reflected in the consolidated statements of cash flows as an operating activity. Performance Unit Compensation. The Company awards performance units and performance share units, which contain a market-based performance component with cash settlement at the end of the performance period, to certain members of senior management. The Company recognizes a liability and expense for performance unit compensation for the portion earned over the requisite service period in an amount equal to the fair value of the performance units granted. Changes in the fair value of the units for which the service requirement has been met are recognized as compensation expense with a corresponding adjustment to the liability. To the extent performance unit compensation cost relates to those directly involved in exploration and development activities, such amounts are capitalized to oil and natural gas properties. Amounts not capitalized are recognized as general and administrative expense, production expense, cost of sales and midstream and marketing expense in the consolidated statements of operations.
Advertising Costs	Advertising Costs. The Company expenses advertising costs as incurred.
Income Taxes	Income Taxes. Deferred income taxes reflect the net tax effects of temporary differences between the amounts of assets and liabilities reported for financial statement purposes and their tax basis. Deferred tax assets are reduced by a valuation allowance if it is deemed more likely than not that some or all of the deferred tax assets will not be realized. The Company has elected an accounting policy in which interest and penalties on income taxes are presented as a component of the income tax provision, rather than as a component of interest expense. Interest and penalties resulting from the underpayment or the late payment of income taxes due to a taxing authority and interest and penalties accrued relating to income tax contingencies, if any, are presented, on a net of tax basis, as a component of the income tax provision.
Earnings per Share	Earnings per Share. Basic earnings per common share is calculated by dividing earnings available to common stockholders by the weighted average number of common shares outstanding during the period. Diluted earnings per common share is calculated by dividing earnings available to common stockholders by the weighted average number of diluted common shares outstanding, which includes the effect of potentially dilutive securities. Potentially dilutive securities for the diluted earnings per share calculation consist of unvested restricted stock awards and restricted share units, using the treasury method, and convertible preferred stock and convertible senior notes, using the if-converted method. Under the treasury method, the amount of unrecognized compensation expense related to unvested stock-based compensation grants is assumed to be used to repurchase shares at the average market price. Under the if-converted method, the Company assumes the conversion of the preferred stock or convertible senior notes to common stock and determines if it is more dilutive than including the preferred stock dividends or expense associated with the convertible senior notes, respectively, in the computation of income available to common stockholders. When a loss exists, all potentially dilutive securities are anti-dilutive and are therefore excluded from the computation of diluted earnings per share. See Note 20 for the Company’s earnings per share calculation.
Commitments and Contingencies	Commitments and Contingencies. Liabilities for loss contingencies arising from claims, assessments, litigation or other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated. Environmental expenditures are expensed or capitalized, as appropriate, depending on future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed. Liabilities related to future costs are recorded on an undiscounted basis when environmental assessments and/or remediation activities are probable and costs can be reasonably estimated. See Note 15 for discussion of the Company’s commitments and contingencies.
Concentration of Risk	Concentration of Risk. All of the Company’s commodity derivative transactions have been carried out in the over-the-counter market. The entry into derivative transactions in the over-the-counter market involves the risk that the counterparties may be unable to meet the financial terms of the transactions. The counterparties for all of the Company’s commodity derivative transactions have an “investment grade” credit rating. The Company monitors on an ongoing basis the credit ratings of its commodity derivative counterparties and considers its counterparties’ credit default risk ratings in determining the fair value of its commodity derivative contracts. The Company’s commodity derivative contracts are with multiple counterparties to minimize its exposure to any individual counterparty. A default by the Company under its senior credit facility constitutes a default under its commodity derivative contracts with counterparties that are lenders under the senior credit facility. The Company does not require collateral or other security from counterparties to support commodity derivative instruments. The Company has master netting agreements with all of its commodity derivative counterparties, which allow the Company to net its commodity derivative assets and liabilities with the same counterparty. As a result of the netting provisions, the Company’s maximum amount of loss under commodity derivative transactions due to credit risk is limited to the net amounts due from the counterparties under the commodity derivative contracts. The Company’s loss is further limited as any amounts due from a defaulting counterparty that is a lender under the senior credit facility can be offset against amounts owed, if any, to such counterparty under the Company’s senior credit facility. The Company operates a substantial portion of its oil and natural gas properties. As the operator of a property, the Company makes full payment for costs associated with the property and seeks reimbursement from the other working interest owners in the property for their share of those costs. The Company’s joint interest partners consist primarily of independent oil and natural gas producers. If the oil and natural gas exploration and production industry in general was adversely affected, the ability of the joint interest partners to reimburse the Company could be adversely affected. The purchasers of the Company’s oil, natural gas and NGL production consist primarily of independent marketers, major oil and natural gas companies and gas pipeline companies. See Note 23 for information regarding the Company’s major customers. The Company believes alternate purchasers are available in its areas of operations and does not believe the loss of any one purchaser would materially affect the Company’s ability to sell the oil, natural gas and NGLs it produces.
Recent Accounting Pronouncements	Recent Accounting Pronouncements. In April 2014, the financial accounting standards board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-08, “Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity”, which amends the definition of a discontinued operations to elevate the threshold for a disposal transaction to qualify as a discontinued operation and requires entities to provide additional disclosures for disposal transactions that do not meet the discontinued operations criteria. The guidance is effective prospectively for all disposals (except disposals classified as held for sale before the adoption date) or components initially classified as held for sale in periods beginning on or after December 15, 2014, with early adoption permitted. The guidance was adopted January 1, 2015 and had no impact for the year ended December 31, 2015. In November 2015, the FASB issued ASU 2015-17, “Balance Sheet Classification of Deferred Taxes”, which requires the classification of all deferred tax assets and liabilities as non-current. The guidance is effective on either a prospective or retrospective basis for periods beginning after December 15, 2016, with early adoption permitted. The Company elected to adopt this guidance on a prospective basis on December 31, 2015, and as such, did not retrospectively adjust prior periods. Since the Company’s deferred tax assets and liabilities are equal and offsetting after including the effect of the valuation allowance, adoption of the guidance resulted in the elimination, for presentation purposes, of a non-current deferred tax asset and a current deferred tax liability on the accompanying consolidated balance sheet at December 31, 2015. Recent Accounting Pronouncements Not Yet Adopted. In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers,” which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance, including industry-specific guidance. The core principle requires that an entity recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. Certain of the provisions also amend or supersede existing guidance applicable to the recognition of a gain or loss on transfers of nonfinancial assets that are not an output of an entity’s ordinary activities, including sales of property, plant and equipment and real estate. In August, 2015, the FASB issued ASU 2015-14, "Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date," which defers the effective date of ASU 2014-09 to annual periods beginning after December 15, 2017, and interim periods within that reporting period. Early adoption is permitted, and either a full retrospective or modified approach may be used for adoption. The Company is currently evaluating the effect, if any, that the updated standard will have on its consolidated financial statements and related disclosures. In August 2014, the FASB issued ASU 2014-15, “Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern,” which provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued. An entity must provide certain disclosures if “conditions or events raise substantial doubt about the entity’s ability to continue as a going concern.” The guidance is effective for annual periods ending after December 15, 2016, and interim periods thereafter, with early adoption permitted. The Company evaluated the effect of the guidance and it will have no impact on its related disclosures. In February 2015, the FASB issued ASU 2015-02, “Amendments to the Consolidation Analysis,” which makes changes to both the variable interest model and the voting model, affecting all reporting entities involved with limited partnerships or similar entities, particularly industries such as the oil and gas, transportation and real estate sectors. In addition to reducing the number of consolidation models from four to two, the guidance simplifies and improves current guidance by placing more emphasis on risk of loss when determining a controlling financial interest and reducing the frequency of the application of related-party guidance when determining a controlling financial interest in a VIE. The requirements of the guidance are effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with early adoption permitted. The Company is currently evaluating the effect that the updated standard will have on its consolidated financial statements and related disclosures. In April 2015, the FASB issued ASU 2015-03, “Simplifying the Presentation of Debt Issuance Costs,” which requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability, consistent with the presentation of a debt discount. The guidance is effective on a retrospective basis for annual periods beginning after December 15, 2015, including interim periods within that reporting period, with early adoption permitted. Adoption of the guidance will result in a decrease to the Company's assets and liabilities in the consolidated balance sheets, with no impact to the consolidated statements of operations. In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842),” which requires companies to recognize the assets and liabilities for the rights and obligations created by long-term leases of assets on the balance sheet. The guidance requires adoption by application of a modified retrospective transition approach for existing long-term leases and is effective for fiscal years beginning after December 15, 2018, including interim periods within those years. The Company is currently evaluating the effect that the guidance will have on its consolidated financial statements and related disclosures. In March 2016, the FASB issued ASU 2016-06, “Contingent Put and Call Options in Debt Instruments” which clarifies the requirements for assessing whether contingent call (put) options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts, which is one of the criteria for bifurcating an embedded derivative. The amendments eliminate diversity in practice in assessing embedded contingent call (put) options in debt instruments. The guidance requires adoption by application of a modified retrospective approach to existing and future debt instruments effective for fiscal years after December 15, 2016, including interim periods within those years. Early adoption is permitted. The Company is currently evaluating the effect that the guidance will have on its consolidated financial statements and related disclosures.
Fair Value Transfers	The Company recognizes transfers between fair value hierarchy levels as of the end of the reporting period in which the event or change in circumstances causing the transfer occurred.

Supplemental Cash Flow Inform34

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2015
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	Supplemental disclosures to the consolidated statements of cash flows are presented below: Years Ended December 31, 2015 2014 2013 (In thousands) Supplemental Disclosure of Cash Flow Information Cash paid for interest, net of amounts capitalized $ (296,386 ) $ (235,793 ) $ (274,850 ) Cash (paid) received for income taxes $ (88 ) $ 1,928 $ (4,610 ) Supplemental Disclosure of Noncash Investing and Financing Activities Deposit on pending sale $ — $ — $ (255,000 ) Change in accrued capital expenditures $ 177,586 $ (55,557 ) $ 72,848 Equity issued for debt $ (63,299 ) $ — $ — Preferred stock dividends paid in common stock $ (16,188 ) $ — $ — Long-term debt issued, including derivative and net of discount, for asset acquisition and termination of gathering agreement $ (50,310 ) $ — $ —

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2015
Gulf Properties
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal, Revenue and Expense Information	The following table presents revenues and expenses, including direct operating expenses, depletion, accretion of asset retirement obligations and general and administrative expenses, for the Gulf Properties included in the accompanying consolidated statements of operations for the years ended December 31, 2014 and 2013 (in thousands): Year Ended December 31, 2014(1) 2013 Revenues $ 90,920 $ 627,236 Expenses $ 63,674 $ 491,991 ____________________ (1) Includes revenues and expenses through February 25, 2014 , the date of the sale.
Permian Properties
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal, Revenue and Expense Information	The following table presents revenues and direct operating expenses of the Permian Properties included in the accompanying consolidated statement of operations for the year ended December 31, 2013 (in thousands): Year Ended December 31, 2013(1) Revenues $ 68,027 Direct operating expenses $ 17,453 ____________________ (1) Includes revenues and direct operating expenses through February 26, 2013, the date of sale.

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	12 Months Ended
	Dec. 31, 2015
Variable Interest Entity [Line Items]
Royalty Trusts Distributions	The following distributions will be paid on February 26, 2016 to holders of record as of the close of business on February 12, 2016 (in thousands): Royalty Trust Total Distribution Amount to be Distributed to Third-Party Unitholders Mississippian Trust I $ 8,708 $ 6,367 Permian Trust 7,560 7,560 Mississippian Trust II 6,825 5,682 Total $ 23,093 $ 19,609
Royalty Trusts
Variable Interest Entity [Line Items]
Schedule of Royalty Trust Units By Class	Common and subordinated units outstanding as of December 31, 2015 and 2014 for each Royalty Trust are as follows: Mississippian Trust I (1) Permian Trust Mississippian Trust II Total outstanding common units 28,000,000 39,375,000 37,293,750 Total outstanding subordinated units(2) — 13,125,000 12,431,250 ____________________ (1) The Mississippian Trust I’s previously outstanding subordinated units, all of which were held by SandRidge, converted to common units on July 1, 2014. (2) All outstanding subordinated units are owned by SandRidge.
Royalty Trusts Ownership Interest	The Company’s beneficial interest in the Royalty Trusts at December 31, 2015 and 2014 were as follows: Mississippian Trust I 26.9 % Permian Trust 25.0 % Mississippian Trust II 37.6 %
Royalty Trusts Distributions	Quarterly distributions declared and paid by the Royalty Trusts during the years ended December 31, 2015 , 2014 and 2013 as follows (in thousands): Year Ended December 31, 2015(1) 2014(2) 2013(3) Total distributions $ 158,632 $ 234,326 $ 299,674 Distributions to third-party unitholders $ 138,305 $ 193,807 $ 206,470 ____________________ (1) Subordination thresholds were not met for the Permian Trust and Mississippian Trust II’s distributions for the year ended December 31, 2015 , resulting in reduced distributions to the Company on its subordinated units for this period. (2) Subordination thresholds were not met for the Mississippian Trust I’s first or second quarter 2014 distributions, the Permian Trust’s second, third or fourth quarter 2014 distributions or for the Mississippian Trust II’s distributions for the year ended December 31, 2014, resulting in reduced distributions to the Company on its subordinated units for these periods. (3) Subordination thresholds were not met for the Mississippian Trust I’s second, third or fourth quarter 2013 distributions, the Permian Trust’s second quarter 2013 distribution or for the Mississippian Trust II’s fourth quarter 2013 distribution, resulting in reduced distributions to the Company on its subordinated units for these periods.
Assets and Liabilities Included in Consolidated Balance Sheets	The Royalty Trusts’ assets and liabilities, after considering the effects of intercompany eliminations, included in the accompanying consolidated balance sheets at December 31, 2015 and 2014 consisted of the following (in thousands): December 31, 2015 2014 Cash and cash equivalents(1) $ 7,824 $ 9,387 Accounts receivable 4,457 17,660 Derivative contracts — 6,589 Total current assets 12,281 33,636 Investment in royalty interests(2) 1,325,942 1,325,942 Less: accumulated depletion and impairment(3) (1,248,957 ) (284,094 ) 76,985 1,041,848 Total assets $ 89,266 $ 1,075,484 Accounts payable and accrued expenses $ 1,060 $ 2,852 Total liabilities $ 1,060 $ 2,852 ____________________ (1) Includes $3.0 million held by the trustee at December 31, 2015 and 2014 as reserves for future general and administrative expenses. (2) Investment in royalty interests is included in oil and natural gas properties in the accompanying consolidated balance sheets. (3) Includes cumulative full cost ceiling limitation impairment of $976.2 million and $42.3 million at December 31, 2015 and 2014 , respectively.
Pinon Gathering Company LLC
Variable Interest Entity [Line Items]
Amounts Due To/From PGC	Amounts due from and due to PGC as of December 31, 2014 included in the accompanying consolidated balance sheet are as follows (in thousands): December 31, 2014 Accounts receivable due from PGC $ 1,141 Accounts payable due to PGC $ 4,163

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Significant Unobservable Inputs - Derivative Contracts	The significant unobservable inputs and the range and weighted average of these inputs used in the fair value measurements of the Company’s natural gas basis swaps at December 31, 2015 and 2014 are included in the table below. Unobservable Input Range Weighted Average Fair Value (Price per Mcf) (In thousands) December 31, 2015 Natural gas basis differential forward curve $ (0.06 ) – $ (0.28 ) $ (0.22 ) $ (1,748 ) December 31, 2014 Natural gas basis differential forward curve $ (0.03 ) – $ (0.38 ) $ (0.29 ) $ 350
Significant Unobservable Inputs - Liabilities	The significant unobservable inputs and range and weighted average of these inputs used in the fair value measurement of the conversion features at December 31, 2015 are included in the table below. Unobservable Input Range Weighted Average Fair Value (In thousands) December 31, 2015 Long-term debt conversion feature hazard rate 114.0 % – 135.2 % 119.2 % $ 29,355
Assets and Liabilities Measured at Fair Value on Recurring Basis	The following tables summarize the Company’s assets and liabilities measured at fair value on a recurring basis by the fair value hierarchy (in thousands): December 31, 2015 Fair Value Measurements Netting(1) Assets/Liabilities at Fair Value Level 1 Level 2 Level 3 Assets Commodity derivative contracts $ — $ 85,524 $ — $ (1,175 ) $ 84,349 Investments 10,106 — — — 10,106 $ 10,106 $ 85,524 $ — $ (1,175 ) $ 94,455 Liabilities Commodity derivative contracts $ — $ — $ 1,748 $ (1,175 ) $ 573 Long-term debt holder conversion feature — — 29,355 — 29,355 Mandatory prepayment feature - PGC Senior Secured Notes — 2,941 — — 2,941 $ — $ 2,941 $ 31,103 $ (1,175 ) $ 32,869 December 31, 2014 Fair Value Measurements Netting(1) Assets/Liabilities at Fair Value Level 1 Level 2 Level 3 Assets Commodity derivative contracts $ — $ 338,067 $ 350 $ — $ 338,417 Investments 11,106 — — — 11,106 $ 11,106 $ 338,067 $ 350 $ — $ 349,523 Liabilities Guarantee $ — $ — $ 5,104 $ — $ 5,104 $ — $ — $ 5,104 $ — $ 5,104 ____________________ (1) Represents the impact of netting assets and liabilities with counterparties with which the right of offset exists.
Fair Value, Reconciliation of Level 3 Fair Value Measurements for Commodity Derivatives	The table below sets forth a reconciliation of the Company’s Level 3 fair value measurements for commodity derivative contracts during the years ended December 31, 2015 , 2014 and 2013 (in thousands): Level 3 Fair Value Measurements - Commodity Derivative Contracts 2015 2014 2013 Beginning balance $ 350 $ — $ (512 ) Loss on commodity derivative contracts (350 ) — (133 ) Purchases (1,748 ) 350 — Settlements paid — — 645 Level 3 commodity derivative contracts at December 31 $ (1,748 ) $ 350 $ —
Fair Value, Reconciliation of Level 3 Fair Value Measurements - Liabilities	The table below sets forth a reconciliation of the Company’s Level 3 fair value measurements for guarantees during the years ended December 31, 2015 and 2014 (in thousands): Level 3 Fair Value Measurements - Guarantee 2015 2014 Beginning balance $ 5,104 $ — Issuances — 9,446 Loss on guarantee — (4,342 ) Settlements (5,104 ) — Ending balance $ — $ 5,104 The table below sets forth a reconciliation of the Company’s Level 3 fair value measurements for long-term debt holder conversion features during the year ended December 31, 2015 (in thousands): Level 3 Fair Value Measurements - Long-Term Debt Holder Conversion Feature Beginning balance $ — Issuances 31,200 Gain on derivative holder conversion feature 10,198 Conversions (12,043 ) Ending balance $ 29,355
Estimated Fair Value and Carrying Value of Senior Notes	The estimated fair values and carrying values of the Company’s senior notes at December 31, 2015 and 2014 were as follows (in thousands): December 31, 2015 December 31, 2014 Fair Value Carrying Value Fair Value Carrying Value 8.75% Senior Secured Notes due 2020(1) $ 403,098 $ 1,301,098 $ — $ — Senior Unsecured Notes 8.75% Senior Notes due 2020(2) $ 39,740 $ 392,666 $ 303,750 $ 445,402 7.5% Senior Notes due 2021(3) $ 79,812 $ 759,711 $ 752,000 $ 1,178,486 8.125% Senior Notes due 2022 $ 57,749 $ 527,737 $ 472,500 $ 750,000 7.5% Senior Notes due 2023(4) $ 58,799 $ 541,572 $ 519,750 $ 821,548 Convertible Senior Unsecured Notes 8.125% Convertible Senior Notes due 2022(5) $ 44,199 $ 82,294 $ — $ — 7.5% Convertible Senior Notes due 2023(6) $ 15,125 $ 26,428 $ — $ — ___________________ (1) Carrying value includes mandatory prepayment feature liabilities with fair value of $2,941 and is net of $29,842 discount at December 31, 2015 . (2) Carrying value is net of $3,269 and $4,598 discount at December 31, 2015 and 2014 , respectively. (3) Carrying value includes a premium of $1,944 and $3,486 at December 31, 2015 and 2014 , respectively. (4) Carrying value is net of $1,989 and $3,452 discount at December 31, 2015 and 2014 , respectively. (5) Carrying value includes holder conversion feature liabilities with fair value of $21,874 and is net of $180,751 discount at December 31, 2015 . (6) Carrying value includes holder conversion feature liabilities with fair value of $7,481 and is net of $59,549 discount at December 31, 2015 .

Accounts Receivable (Tables)

Accounts Receivable (Tables)	12 Months Ended
	Dec. 31, 2015
Receivables [Abstract]
Summary of Accounts Receivable	A summary of accounts receivable is as follows (in thousands): December 31, 2015 2014 Oil, natural gas and NGL sales $ 61,140 $ 139,848 Joint interest billing 60,403 170,937 Oil and natural gas services 2,417 21,436 Other 8,274 4,939 132,234 337,160 Less: allowance for doubtful accounts (4,847 ) (7,083 ) Total accounts receivable, net $ 127,387 $ 330,077
Balance and Activity in Allowance for Doubtful Accounts	The following table presents the balance and activity in the allowance for doubtful accounts for the years ended December 31, 2015 , 2014 and 2013 (in thousands): Year Ended December 31, 2015 2014 2013 Beginning balance $ 7,083 $ 11,061 $ 5,635 Additions charged to costs and expenses(1) 1,320 818 5,497 Deductions(2) (3,556 ) (4,796 ) (71 ) Ending balance $ 4,847 $ 7,083 $ 11,061 ____________________ (1) Includes $2.7 million of allowance for receivables deemed uncollectible at December 31, 2013, primarily due to the bankruptcy status of customers. (2) Deductions represent write-off of receivables and collections of amounts for which an allowance had previously been established. Deductions in 2015 are primarily due to the write-off of receivables in conjunction with a lawsuit settlement, and deductions in 2014 are related to the sale of the Gulf Properties.

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment consists of the following (in thousands): December 31, 2015 2014 Oil and natural gas properties Proved(1) $ 12,529,681 $ 11,707,147 Unproved 363,149 290,596 Total oil and natural gas properties 12,892,830 11,997,743 Less accumulated depreciation, depletion and impairment (11,149,888 ) (6,359,149 ) Net oil and natural gas properties capitalized costs 1,742,942 5,638,594 Land 14,260 16,300 Non-oil and natural gas equipment(2) 373,687 602,392 Buildings and structures(3) 227,673 263,191 Total 615,620 881,883 Less accumulated depreciation and amortization (123,860 ) (305,420 ) Other property, plant and equipment, net 491,760 576,463 Total property, plant and equipment, net $ 2,234,702 $ 6,215,057 ____________________ (1) Includes cumulative capitalized interest of approximately $48.9 million and $38.1 million at December 31, 2015 and 2014 , respectively. (2) Includes cumulative capitalized interest of approximately $4.3 million at both December 31, 2015 and 2014 . (3) Includes cumulative capitalized interest of approximately $20.4 million and $17.1 million at December 31, 2015 and 2014 , respectively.
Capitalized Costs of Unproved Properties Excluded from Amortization	The following table summarizes the costs, by year incurred, related to unproved properties and pipe inventory, which were excluded from oil and natural gas properties subject to amortization at December 31, 2015 (in thousands): Year Cost Incurred Total 2015 2014 2013 2012 and Prior Property acquisition $ 362,803 $ 197,849 $ 70,304 $ 14,011 $ 80,639 Exploration(1) 34,988 10,698 6,263 17,688 339 Total costs incurred $ 397,791 $ 208,547 $ 76,567 $ 31,699 $ 80,978 ____________________ (1) Includes $34.7 million of pipe inventory costs incurred ( $10.5 million in 2015 , $6.2 million in 2014 and $18.0 million in 2013 and prior years).

Other Assets (Tables)

Other Assets (Tables)	12 Months Ended
	Dec. 31, 2015
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Other Assets	Other assets consist of the following (in thousands): December 31, 2015 2014 Debt issuance costs, net of amortization $ 72,259 $ 56,445 Deferred tax asset(1) — 95,843 Investments 10,106 11,106 Other — 1,853 Total other assets $ 82,365 $ 165,247 ____________________ (1) The deferred tax asset at December 31, 2015, upon which there is a full valuation allowance, was netted against the deferred tax liability for presentation purposes as a result of the Company’s adoption of ASU 2015-17 in the fourth quarter of 2015. See Note 1 .

Accounts Payable and Accrued 41

Accounts Payable and Accrued Expenses (Tables)	12 Months Ended
	Dec. 31, 2015
Payables and Accruals [Abstract]
Accounts Payable and Accrued Expenses	Accounts payable and accrued expenses consist of the following (in thousands): December 31, 2015 2014 Accounts payable and other accrued expenses $ 231,697 $ 392,500 Accrued interest 73,320 79,704 Production payable 55,260 120,573 Payroll and benefits 42,728 44,496 Convertible perpetual preferred stock dividends 21,572 11,072 Drilling advances 2,295 33,195 Related party 1,545 1,852 Total accounts payable and accrued expenses $ 428,417 $ 683,392

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Long-Term Debt	Long-term debt consists of the following (in thousands): December 31, 2015 2014 Senior credit facility $ — $ — 8.75% Senior Secured Notes due 2020, including mandatory prepayment feature liabilities of $2,941, and net of $29,842 discount 1,301,098 — Senior Unsecured Notes 8.75% Senior Notes due 2020, net of $3,269 and $4,598 discount, respectively 392,666 445,402 7.5% Senior Notes due 2021, including a premium of $1,944 and $3,486, respectively 759,711 1,178,486 8.125% Senior Notes due 2022 527,737 750,000 7.5% Senior Notes due 2023, net of $1,989 and $3,452 discount, respectively 541,572 821,548 Convertible Senior Unsecured Notes 8.125% Convertible Senior Notes due 2022, including holder conversion feature liabilities of $21,874, and net of $180,751 discount 82,294 — 7.5% Convertible Senior Notes due 2023, including holder conversion feature liabilities of $7,481, and net of $59,549 discount 26,428 — Total debt 3,631,506 3,195,436 Less: current maturities of long-term debt — — Long-term debt $ 3,631,506 $ 3,195,436

Derivatives (Tables)

Derivatives (Tables)	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Offsetting Assets and Liabilities	The following tables summarize (i) the Company's commodity derivative contracts on a gross basis, (ii) the effects of netting assets and liabilities for which the right of offset exists based on master netting arrangements and (iii) for the Company’s net derivative liability positions, the applicable portion of shared collateral under the senior credit facility (in thousands): December 31, 2015 Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount Assets Derivative contracts - current $ 85,524 $ (1,175 ) $ 84,349 $ — $ 84,349 Derivative contracts - noncurrent — — — — — Total $ 85,524 $ (1,175 ) $ 84,349 $ — $ 84,349 Liabilities Derivative contracts - current $ 1,748 $ (1,175 ) $ 573 $ (573 ) $ — Derivative contracts - noncurrent — — — — — Total $ 1,748 $ (1,175 ) $ 573 $ (573 ) $ — December 31, 2014 Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount Assets Derivative contracts - current $ 291,414 $ — $ 291,414 $ — $ 291,414 Derivative contracts - noncurrent 47,003 — 47,003 — 47,003 Total $ 338,417 $ — $ 338,417 $ — $ 338,417 Liabilities Derivative contracts - current $ — $ — $ — $ — $ — Derivative contracts - noncurrent — — — — — Total $ — $ — $ — $ — $ —
Open Oil and Natural Gas Commodity Derivative Contracts	At December 31, 2015 , the Company’s open commodity derivative contracts consisted of the following: Oil Price Swaps Notional (MBbls) Weighted Average Fixed Price January 2016 - December 2016 1,464 $ 88.36 Natural Gas Basis Swaps Notional (MMcf) Weighted Average Fixed Price January 2016 - December 2016 10,980 $ (0.38 ) Oil Collars - Three-way Notional (MBbls) Sold Put Purchased Put Sold Call January 2016 - December 2016 2,556 $ 83.14 $ 90.00 $ 100.85
Fair Value of Derivative Contracts	The following table presents the fair value of the Company’s derivative contracts as of December 31, 2015 and 2014 on a gross basis without regard to same-counterparty netting (in thousands): December 31, Type of Contract Balance Sheet Classification 2015 2014 Derivative assets Oil price swaps Derivative contracts—current $ 68,224 $ 204,072 Natural gas price swaps Derivative contracts—current — 29,648 Natural gas basis swaps Derivative contracts—current — 350 Oil collars—three way Derivative contracts—current 17,300 56,289 Natural gas collars Derivative contracts—current — 1,055 Oil price swaps Derivative contracts—noncurrent — 36,288 Oil collars—three way Derivative contracts—noncurrent — 10,715 Derivative liabilities Natural gas basis swaps Derivative contracts—current (1,748 ) — Long-term debt holder conversion feature Long-term debt (29,355 ) — Mandatory prepayment feature - PGC Senior Secured Notes Long-term debt (2,941 ) — Total net derivative contracts $ 51,480 $ 338,417

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Reconciliation of Beginning and Ending Aggregate Carrying Amounts of Asset Retirement Obligations	The following table presents the balance and activity of the asset retirement obligations for the years ended December 31, 2015 , 2014 and 2013 (in thousands). 2015 2014 2013 Beginning balance $ 54,402 $ 424,117 $ 498,410 Liability incurred upon acquiring and drilling wells 1,662 4,968 5,078 Revisions in estimated cash flows(1) 44,060 (5,848 ) (3,077 ) Liability settled or disposed in current period(2) (1,023 ) (377,927 ) (113,071 ) Accretion 4,477 9,092 36,777 Ending balance 103,578 54,402 424,117 Less: current portion 8,399 — 87,063 Asset retirement obligations, net of current $ 95,179 $ 54,402 $ 337,054 ____________________ (1) Revisions for the year ended December 31, 2015 relate primarily to changes in estimated well lives. (2) Liability settled or disposed for the year ended December 31, 2014, includes $366.0 million associated with the Gulf Properties sold in February 2014, as discussed in Note 3 .

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Future Minimum Rental Payments for Operating Leases	Future minimum payments under noncancelable operating leases (with initial lease terms exceeding one year) as of December 31, 2015 were as follows (in thousands): Years ending December 31 2016 $ 584 2017 555 2018 485 2019 72 2020 — Thereafter — $ 1,696
Oil and Natural Gas Transportation and Throughput Obligations	The amounts of the required payments related to the transportation and throughput agreements as of December 31, 2015 were as follows (in thousands): Years ending December 31 2016 $ 14,082 2017 13,869 2018 14,163 2019 9,282 2020 1,584 Thereafter 11,088 $ 64,068

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2015
Stockholders Equity Note [Line Items]
Preferred Stock Terms	The following table summarizes information about each series of the Company’s convertible perpetual preferred stock outstanding at December 31, 2015 : Convertible Perpetual Preferred Stock 8.5% 7.0% Liquidation preference per share $ 100.00 $ 100.00 Annual dividend per share $ 8.50 $ 7.00 Conversion rate per share to common stock 12.4805 12.8791
Preferred Stock Dividends	Preferred stock dividend payments and accruals for the Company’s 8.5% , 7.0% and 6.0% convertible perpetual preferred stock for the years ended December 31, 2015 , 2014 and 2013 are as follows: December 31, 2015 2014 2013 (In thousands) 8.5% Convertible perpetual preferred stock Dividends paid in cash $ 11,262 $ 22,525 $ 22,525 Dividends satisfied in shares of common stock(1) $ 11,262 $ — $ — Accrued dividends at period end $ 8,447 $ 8,447 $ 8,447 7.0% Convertible perpetual preferred stock Dividends paid in cash $ — $ 21,000 $ 21,000 Dividends satisfied in shares of common stock(2) $ 10,500 $ — $ — Accrued dividends at period end $ 13,125 $ 2,625 $ 2,625 Dividends in arrears(3) $ 10,500 $ — $ — 6.0% Convertible perpetual preferred stock (4) Dividends paid in cash $ — $ 12,000 $ 12,000 Accrued dividends at period end $ — $ — $ 5,500 ____________________ (1) For the year ended December 31, 2015 , the Company paid a semi-annual dividend by issuing approximately 18.6 million shares of common stock. For purposes of the dividend payment, the value of each share issued was calculated as 95% of the average volume-weighted share price for the 15 trading day period ending July 29, 2015. Based upon the common stock’s closing price on August 17, 2015, the common stock issued had a market value of approximately $9.5 million , ( $3.58 per outstanding share at the time the dividend was paid) that resulted in a difference between the fixed rate semi-annual dividend and the value of shares issued of approximately $1.8 million , which was recorded as a reduction to preferred stock dividends in the accompanying condensed consolidated statement of operations. (2) For the year ended December 31, 2015 , the Company paid a semi-annual dividend by issuing approximately 5.7 million shares of common stock. For purposes of the dividend payment, the value of each share issued was calculated as 95% of the average volume-weighted share price for the 15 trading day period ending April 28, 2015. Based upon the common stock’s closing price on May 15, 2015, the common stock issued had a market value of approximately $6.7 million , ( $2.23 per outstanding share at the time the dividend was paid) that resulted in a difference between the fixed rate semi-annual dividend and the value of shares issued of approximately $3.8 million , which was recorded as a reduction to preferred stock dividends in the accompanying condensed consolidated statement of operations. (3) In the third quarter of 2015, the Company announced the suspension of payment of the semi-annual dividend on shares of its 7.0% convertible perpetual preferred stock. (4) The final dividend payment for the 6.0% convertible preferred stock was made during 2014.
Treasury Stock Activity	The following table shows the number of shares withheld for taxes and the associated value of those shares for the years ended December 31, 2015 , 2014 and 2013 . These shares were accounted for as treasury stock when withheld, and then immediately retired. Year Ended December 31, 2015 2014 2013 (In thousands) Number of shares withheld for taxes 1,872 1,034 5,679 Value of shares withheld for taxes $ 2,428 $ 6,373 $ 30,126
Preferred Stock
Stockholders Equity Note [Line Items]
Schedule of Stock by Class	The following table presents information regarding the Company’s preferred stock (in thousands): December 31, 2015 2014 Shares authorized, $0.001 par value 50,000 50,000 Shares outstanding at end of period 8.5% Convertible perpetual preferred stock 2,650 2,650 7.0% Convertible perpetual preferred stock(1) 2,770 3,000 ____________________ (1) For the year ended December 31, 2015 , approximately 230,500 shares were converted into approximately 3.0 million shares of the Company’s common stock.
Common Stock
Stockholders Equity Note [Line Items]
Schedule of Stock by Class	The following table presents information regarding the Company’s common stock (in thousands): December 31, 2015 2014 Shares authorized 1,800,000 800,000 Shares outstanding at end of period 633,471 484,819 Shares held in treasury 2,113 1,113

Share-Based Compensation (Table

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of Unvested Restricted Stock Awards	The following table presents a summary of the Company’s unvested restricted stock awards. Number of Shares Weighted- Average Grant Date Fair Value (In thousands) Unvested restricted shares outstanding at December 31, 2012 15,328 $ 8.07 Granted 7,462 $ 6.32 Vested (13,395 ) $ 7.85 Forfeited / Canceled (1,752 ) $ 7.33 Unvested restricted shares outstanding at December 31, 2013 7,643 $ 6.92 Granted 6,367 $ 6.17 Vested (3,432 ) $ 7.04 Forfeited / Canceled (2,022 ) $ 6.60 Unvested restricted shares outstanding at December 31, 2014 8,556 $ 6.39 Granted 2,928 $ 0.88 Vested (5,186 ) $ 4.95 Forfeited / Canceled (672 ) $ 6.38 Unvested restricted shares outstanding at December 31, 2015 5,626 $ 4.85
Summary of Unvested Restricted Stock Units	The following table presents a summary of the Company’s unvested restricted stock units which may be settled in shares of the Company’s common stock, cash or some combination of common stock and cash at the Company’s election. These restricted stock units are liability-classified awards, which vest ratably over a maximum four -year period from the date of grant and were valued at December 31, 2015 based upon the Company’s period end common stock price. Number of Units Fair Value per Unit at December 31, 2015 (In thousands) Unvested units outstanding at December 31, 2014 — Granted 11,095 Vested(1) (2,200 ) Forfeited / Canceled (767 ) Unvested units outstanding at December 31, 2015 8,128 $ 0.20 ____________________ (1) Restricted stock units which vested during the year ended December 31, 2015 were settled by the issuance of common stock. The restricted stock units were valued based upon the Company’s period end common stock price, discounted using a credit spread ( 10.6% at December 31, 2015 ) that was determined based upon an analysis of the historical option adjusted spread for the Company’s outstanding senior notes and the outstanding long-term debt of comparable companies. Number of Units Fair Value per Unit at December 31, 2015 (In thousands) Unvested units outstanding at December 31, 2014 — Granted 3,104 Vested (979 ) Forfeited / Canceled (122 ) Unvested units outstanding at December 31, 2015 2,003 $ 0.04 - $ 0.20
Performance Units/Performance Share Units Fair Value Assumptions	The following table presents a summary of the fair values of the performance units granted during the years ended December 31, 2014 and 2013 and the related assumptions for all outstanding performance units at December 31, 2015 and 2014 . December 31, 2015 2014 Volatility factor 120.0 % 55.6 % Weighted-average risk-free interest rate 0.7 % 0.5 % Weighted-average fair value per unit $ 1.08 $ 13.85 The following table presents a summary of the fair values of the performance share units granted and the related assumptions for all outstanding performance share units at December 31, 2015 . December 31, 2015 Volatility factor 95.3 % Weighted-average risk-free interest rate 1.1 % Weighted-average fair value per unit $ 0.10
Performance Units/Performance Share Units Outstanding Activity	Performance share unit activity for the year ended December 31, 2015 was as follows: Number of Performance Share Units (In thousands) Outstanding at December 31, 2014 — Granted 2,044 Forfeited /canceled (151 ) Outstanding at December 31, 2015 1,893 Performance period ending December 31, 2017 Vested 695 Unvested 1,198 Performance unit activity for the years ended December 31, 2015 , 2014 and 2013 was as follows (in thousands): December 31, 2015 2014 2013(1) Outstanding at January 1 66 31 — Granted — 47 31 Vested (28 ) — — Forfeited /canceled — (12 ) — Outstanding at December 31 38 66 31 Performance period ending December 31, 2015 Vested — 9 12 Unvested — 19 19 Performance period ending December 31, 2016 Vested 26 13 — Unvested 12 25 — ____________________ (1) The 2013 performance units fully vested on December 31, 2015, with no amounts paid.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
(Benefit) Provision for Income Taxes	The Company’s income tax provision (benefit) consisted of the following components for the years ended December 31, 2015 , 2014 and 2013 (in thousands): Year Ended December 31, 2015 2014 2013 Current Federal $ — $ (1,160 ) $ 3,842 State 123 (1,133 ) 1,842 123 (2,293 ) 5,684 Deferred Federal — — — State — — — — — — Total provision (benefit) 123 (2,293 ) 5,684 Less: income tax provision attributable to noncontrolling interest 90 283 308 Total provision (benefit) attributable to SandRidge Energy, Inc. $ 33 $ (2,576 ) $ 5,376
Reconciliation of Provision (Benefit) for Income Taxes at Statutory Federal Tax Rate	A reconciliation of the provision (benefit) for income taxes at the statutory federal tax rate to the Company’s actual income tax benefit is as follows for the years ended December 31, 2015 , 2014 and 2013 (in thousands): 2015 2014 2013 Computed at federal statutory rate $ (1,512,325 ) $ 122,362 $ (178,078 ) State taxes, net of federal benefit (19,988 ) 4,145 (886 ) Non-deductible expenses 816 1,895 2,589 Non-deductible debt costs 10,228 — — Stock-based compensation 6,700 1,467 7,611 Net effects of consolidating the non-controlling interests’ tax provisions 218,196 (34,614 ) (13,901 ) Change in valuation allowance 1,296,405 (96,769 ) 188,599 Other 1 (1,062 ) (558 ) Total provision (benefit) attributable to SandRidge Energy, Inc. $ 33 $ (2,576 ) $ 5,376
Deferred Tax Assets and Liabilities	Significant components of the Company’s deferred tax assets and liabilities are as follows (in thousands): December 31, 2015 2014 Deferred tax liabilities Investments(1) $ 138,310 $ 272,902 Property, plant and equipment — 364,576 Derivative contracts 30,989 113,735 Long-term debt 10,017 — Total deferred tax liabilities 179,316 751,213 Deferred tax assets Property, plant and equipment 807,275 — Allowance for doubtful accounts 18,702 19,086 Net operating loss carryforwards 1,190,799 1,265,458 Compensation and benefits 18,607 19,867 Alternative minimum tax credits and other carryforwards 44,302 43,840 Asset retirement obligations 38,314 21,946 CO 2 under-delivery shortfall penalty 40,654 27,674 Other 4,305 2,934 Total deferred tax assets 2,162,958 1,400,805 Valuation allowance (1,983,642 ) (649,592 ) Net deferred tax liability $ — $ — ____________________ (1) Includes the Company’s deferred tax liability resulting from its investment in the Royalty Trusts. See Note 4 for further discussion of the Royalty Trusts.
Unrecognized Tax Benefits	A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows (in thousands): December 31, 2015 2014 Unrecognized tax benefit at January 1 $ 77 $ 1,382 Changes to unrecognized tax benefits related to a prior year 4 (17 ) Decreases to unrecognized tax benefits for settlements with tax authorities — (1,288 ) Unrecognized tax benefit at December 31 $ 81 $ 77

(Loss) Earnings per Share (Tabl

(Loss) Earnings per Share (Tables)	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Calculation of Weighted Average Common Shares Outstanding used in Computation of Diluted Earnings Per Share	The following table summarizes the calculation of weighted average common shares outstanding used in the computation of diluted earnings per share, for the years ended December 31, 2015 , 2014 and 2013 (in thousands): Net (Loss) Income Weighted Average Shares (Loss) Earnings Per Share (In thousands, except per share amounts) Year Ended December 31, 2015 Basic loss per share $ (3,735,495 ) 521,936 $ (7.16 ) Effect of dilutive securities Restricted stock and units(1) — — Convertible preferred stock(2) — — Convertible senior unsecured notes(3) — — Diluted loss per share $ (3,735,495 ) 521,936 $ (7.16 ) Year Ended December 31, 2014 Basic earnings per share $ 203,260 479,644 $ 0.42 Effect of dilutive securities Restricted stock — 2,181 Convertible preferred stock(2) 6,500 17,918 Diluted earnings per share $ 209,760 499,743 $ 0.42 Year Ended December 31, 2013 Basic loss per share $ (609,414 ) 481,148 $ (1.27 ) Effect of dilutive securities Restricted stock(4) — — Convertible preferred stock(5) — — Diluted loss per share $ (609,414 ) 481,148 $ (1.27 ) ____________________ (1) No incremental shares of potentially dilutive restricted stock awards or units were included for the year ended December 31, 2015 as their effect was antidilutive under the treasury stock method. (2) Potential common shares related to the Company’s outstanding 8.5% and 7.0% convertible perpetual preferred stock covering 71.2 million and 71.7 million shares for the years ended December 31, 2015 and 2014 , respectively, were excluded from the computation of (loss) earnings per share because their effect would have been antidilutive under the if-converted method. (3) Potential common shares related to the Company’s outstanding 8.125% and 7.5% Convertible Senior Unsecured Notes covering 48.5 million shares for the year ended December 31, 2015 were excluded from the computation of loss per share because their effect would have been antidilutive under the if-converted method. (4) Restricted stock awards covering 0.5 million shares were excluded from the computation of loss per share because their effect would have been antidilutive. (5) Potential common shares related to the Company’s outstanding 8.5% , 6.0% and 7.0% convertible perpetual preferred stock covering 90.1 million shares for the year ended December 31, 2013 were excluded from the computation of loss per share because their effect would have been antidilutive under the if-converted method.

Subsequent Events (Tables)

Subsequent Events (Tables)	12 Months Ended
	Dec. 31, 2015
Subsequent Events [Abstract]
Royalty Trust Distributions	The following distributions will be paid on February 26, 2016 to holders of record as of the close of business on February 12, 2016 (in thousands): Royalty Trust Total Distribution Amount to be Distributed to Third-Party Unitholders Mississippian Trust I $ 8,708 $ 6,367 Permian Trust 7,560 7,560 Mississippian Trust II 6,825 5,682 Total $ 23,093 $ 19,609

Business Segment Information (T

Business Segment Information (Tables)	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Summarized Financial Information Concerning Segments	Summarized financial information concerning the Company’s segments is shown in the following table (in thousands): Exploration and Production(1) Drilling and Oil Field Services(2) Midstream Services(3) All Other(4) Consolidated Total Year Ended December 31, 2015 Revenues $ 707,446 $ 67,358 $ 81,083 $ 5,342 $ 861,229 Inter-segment revenue (12 ) (45,234 ) (47,274 ) — (92,520 ) Total revenues $ 707,434 $ 22,124 $ 33,809 $ 5,342 $ 768,709 Loss from operations $ (4,461,907 ) $ (59,999 ) $ (15,218 ) $ (105,554 ) $ (4,642,678 ) Interest expense, net (42 ) — — (321,379 ) (321,421 ) Gain on extinguishment of debt — — — 641,131 641,131 Other income, net 1,368 13 253 406 2,040 Loss before income taxes $ (4,460,581 ) $ (59,986 ) $ (14,965 ) $ 214,604 $ (4,320,928 ) Capital expenditures(5) $ 656,022 $ 4,632 $ 21,556 $ 19,405 $ 701,615 Depreciation, depletion, amortization and accretion $ 324,471 $ 17,438 $ 11,742 $ 18,121 $ 371,772 At December 31, 2015 Total assets $ 1,959,975 $ 27,621 $ 254,212 $ 749,347 $ 2,991,155 Year Ended December 31, 2014 Revenues $ 1,423,073 $ 192,944 $ 142,987 $ 4,376 $ 1,763,380 Inter-segment revenue (173 ) (116,856 ) (87,593 ) — (204,622 ) Total revenues $ 1,422,900 $ 76,088 $ 55,394 $ 4,376 $ 1,558,758 Income (loss) from operations $ 713,716 $ (37,564 ) $ (9,094 ) $ (76,834 ) $ 590,224 Interest income (expense), net 100 — — (244,209 ) (244,109 ) Other (expense) income, net (423 ) (541 ) 9 4,445 3,490 Income (loss) before income taxes $ 713,393 $ (38,105 ) $ (9,085 ) $ (316,598 ) $ 349,605 Capital expenditures(5) $ 1,508,100 $ 18,385 $ 44,606 $ 37,798 $ 1,608,889 Depreciation, depletion, amortization and accretion $ 443,573 $ 29,105 $ 10,085 $ 20,260 $ 503,023 At December 31, 2014 Total assets $ 6,273,802 $ 115,083 $ 219,691 $ 650,649 $ 7,259,225 Year Ended December 31, 2013 Revenues $ 1,834,480 $ 187,456 $ 179,989 $ 3,127 $ 2,205,052 Inter-segment revenue (320 ) (120,815 ) (100,529 ) — (221,664 ) Total revenues $ 1,834,160 $ 66,641 $ 79,460 $ 3,127 $ 1,983,388 Income (loss) from operations $ 62,509 $ (40,155 ) $ (21,567 ) $ (169,788 ) $ (169,001 ) Interest income (expense), net 1,168 — (209 ) (271,193 ) (270,234 ) Loss on extinguishment of debt — — — (82,005 ) (82,005 ) Other income (expense), net 5,487 — (3,222 ) 10,180 12,445 Income (loss) before income taxes $ 69,164 $ (40,155 ) $ (24,998 ) $ (512,806 ) $ (508,795 ) Capital expenditures(5) $ 1,319,012 $ 7,125 $ 55,706 $ 42,040 $ 1,423,883 Depreciation, depletion, amortization and accretion $ 605,242 $ 33,291 $ 7,972 $ 20,140 $ 666,645 ____________________ (1) (Loss) income from operations includes full cost ceiling limitation impairments of $4.5 billion and $164.8 million for the years ended December 31, 2015 and 2014 , respectively, a loss on the sale of the Permian Properties of $398.9 million for the year ended December 31, 2013 and the Company’s (gain) loss on derivative contracts, including net cash payments upon settlement, for the years ended December 31, 2015 , 2014 and 2013 . See Note 13 for discussion of derivative contracts. (2) For the years ended December 31, 2015 , 2014 and 2013 , (loss) income from operations includes impairments of $37.6 million , $27.4 million , and $11.1 million , respectively, on certain drilling assets. (3) For the years ended December 31, 2015 , 2014 and 2013 , (loss) income from operations includes impairments of other midstream assets and the Company’s gas treating plants in west Texas of $7.1 million , $0.6 million and $3.9 million , respectively. (4) (Loss) income from operations for the year ended December 31, 2015 includes an impairment of $15.4 million on property located in downtown Oklahoma City, Oklahoma and $0.7 million on gathering and compression equipment. See Note 7 . For the year ended December 31, 2013, (loss) income from operations includes a $2.9 million impairment of a corporate asset and an $8.3 million impairment of the Company’s CO 2 compression facilities. (5) On an accrual basis and exclusive of acquisitions.
Major Customers	Major Customers. For the years ended December 31, 2015 , 2014 and 2013 , the Company had sales exceeding 10% of total revenues to the following oil and natural gas purchasers (in thousands): 2015 Sales % of Revenue Plains Marketing, L.P. $ 318,018 41.4 % Targa Pipeline Mid-Continent West OK LLC $ 231,649 30.1 % 2014 Sales % of Revenue Plains Marketing, L.P. $ 597,117 38.3 % Targa Pipeline Mid-Continent West OK LLC $ 333,027 21.4 % 2013 Sales % of Revenue Plains Marketing, L.P. $ 491,258 24.8 % Shell Trading (US) Company $ 347,422 17.5 % Targa Pipeline Mid-Continent West OK LLC $ 211,838 10.7 %

Condensed Consolidating Finan52

Condensed Consolidating Financial Information (Tables)	12 Months Ended
	Dec. 31, 2015
Condensed Consolidating Financial Statements Disclosure [Abstract]
Condensed Consolidating Balance Sheets of SandRidge Energy, Inc. and Wholly Owned Subsidiary Guarantors and Non-Guarantors	Condensed Consolidating Balance Sheets December 31, 2015 Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) ASSETS Current assets Cash and cash equivalents $ 426,917 $ 847 $ 7,824 $ — $ 435,588 Accounts receivable, net — 122,606 4,781 — 127,387 Intercompany accounts receivable 1,226,994 1,305,573 30,683 (2,563,250 ) — Derivative contracts — 84,349 — — 84,349 Prepaid expenses — 6,826 7 — 6,833 Other current assets — 19,931 — — 19,931 Total current assets 1,653,911 1,540,132 43,295 (2,563,250 ) 674,088 Property, plant and equipment, net — 2,124,532 110,170 — 2,234,702 Investment in subsidiaries 2,749,514 8,531 — (2,758,045 ) — Other assets 72,259 16,008 — (5,902 ) 82,365 Total assets $ 4,475,684 $ 3,689,203 $ 153,465 $ (5,327,197 ) $ 2,991,155 LIABILITIES AND STOCKHOLDERS’ (DEFICIT) EQUITY Current liabilities Accounts payable and accrued expenses $ 160,122 $ 265,767 $ 2,528 $ — $ 428,417 Intercompany accounts payable 1,337,688 1,192,569 32,993 (2,563,250 ) — Derivative contracts — 573 — — 573 Asset retirement obligations — 8,399 — — 8,399 Total current liabilities 1,497,810 1,467,308 35,521 (2,563,250 ) 437,389 Investment in subsidiaries 1,038,303 400,771 — (1,439,074 ) — Long-term debt 3,637,408 — — (5,902 ) 3,631,506 Asset retirement obligations — 95,179 — — 95,179 Other long-term obligations 80 14,734 — — 14,814 Total liabilities 6,173,601 1,977,992 35,521 (4,008,226 ) 4,178,888 Stockholders’ (Deficit) Equity SandRidge Energy, Inc. stockholders’ (deficit) equity (1,697,917 ) 1,711,211 117,944 (1,829,155 ) (1,697,917 ) Noncontrolling interest — — — 510,184 510,184 Total stockholders’ (deficit) equity (1,697,917 ) 1,711,211 117,944 (1,318,971 ) (1,187,733 ) Total liabilities and stockholders’ (deficit) equity $ 4,475,684 $ 3,689,203 $ 153,465 $ (5,327,197 ) $ 2,991,155 December 31, 2014 Parent(1) Guarantors(1)(2) Non-Guarantors(3) Eliminations(2)(3) Consolidated (In thousands) ASSETS Current assets Cash and cash equivalents $ 170,468 $ 1,398 $ 9,387 $ — $ 181,253 Accounts receivable, net 7 299,764 30,313 (7 ) 330,077 Intercompany accounts receivable 751,376 1,339,152 41,679 (2,132,207 ) — Derivative contracts — 284,825 45,043 (38,454 ) 291,414 Prepaid expenses — 7,971 10 — 7,981 Other current assets — 21,193 — — 21,193 Total current assets 921,851 1,954,303 126,432 (2,170,668 ) 831,918 Property, plant and equipment, net — 5,137,702 1,077,355 — 6,215,057 Investment in subsidiaries 6,606,198 25,944 — (6,632,142 ) — Derivative contracts — 47,003 — — 47,003 Other assets 152,286 18,197 666 (5,902 ) 165,247 Total assets $ 7,680,335 $ 7,183,149 $ 1,204,453 $ (8,808,712 ) $ 7,259,225 LIABILITIES AND EQUITY Current liabilities Accounts payable and accrued expenses $ 151,825 $ 526,941 $ 4,633 $ (7 ) $ 683,392 Intercompany accounts payable 1,365,210 731,103 35,894 (2,132,207 ) — Derivative contracts — 38,454 — (38,454 ) — Deferred tax liability 95,843 — — — 95,843 Other current liabilities — 5,216 — — 5,216 Total current liabilities 1,612,878 1,301,714 40,527 (2,170,668 ) 784,451 Investment in subsidiaries 928,217 134,013 — (1,062,230 ) — Long-term debt 3,201,338 — — (5,902 ) 3,195,436 Asset retirement obligations — 54,402 — — 54,402 Other long-term obligations 77 15,039 — — 15,116 Total liabilities 5,742,510 1,505,168 40,527 (3,238,800 ) 4,049,405 Equity SandRidge Energy, Inc. stockholders’ equity 1,937,825 5,677,981 1,163,926 (6,841,907 ) 1,937,825 Noncontrolling interest — — — 1,271,995 1,271,995 Total equity 1,937,825 5,677,981 1,163,926 (5,569,912 ) 3,209,820 Total liabilities and equity $ 7,680,335 $ 7,183,149 $ 1,204,453 $ (8,808,712 ) $ 7,259,225 ____________________ (1) Parent accounts payable and accrued expenses have decreased and intercompany accounts payable have increased by approximately $49.5 million for amounts previously misclassified. Guarantor accounts payable and accrued expenses have increased and intercompany accounts payable have decreased by a corresponding amount. (2) Amounts presented as property, plant and equipment have been revised to include approximately $150.4 million previously misclassified as investment in subsidiary. (3) Amounts previously misclassified as property, plant and equipment and SandRidge Energy, Inc. stockholders’ equity totaling approximately $150.4 million are now presented as Guarantor property, plant and equipment.
Condensed Consolidating Statements of Operations of SandRidge Energy, Inc. and Wholly Owned Subsidiary Guarantors and Non-Guarantors	Condensed Consolidating Statements of Operations Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Year Ended December 31, 2015 Total revenues $ — $ 682,778 $ 85,939 $ (8 ) $ 768,709 Expenses Direct operating expenses — 364,483 10,879 (8 ) 375,354 General and administrative 213 145,796 4,157 — 150,166 Depreciation, depletion, amortization and accretion — 339,647 32,125 — 371,772 Impairment — 3,599,810 934,879 — 4,534,689 Gain on derivative contracts — (65,049 ) (8,012 ) — (73,061 ) Loss on settlement of contract — 50,976 — — 50,976 Loss (gain) on sale of assets — 2,217 (726 ) — 1,491 Total expenses 213 4,437,880 973,302 (8 ) 5,411,387 Loss from operations (213 ) (3,755,102 ) (887,363 ) — (4,642,678 ) Equity earnings from subsidiaries (4,017,082 ) (263,847 ) — 4,280,929 — Interest expense, net (321,378 ) (43 ) — — (321,421 ) Gain on extinguishment of debt 641,131 — — — 641,131 Other income, net — 1,910 130 — 2,040 Loss before income taxes (3,697,542 ) (4,017,082 ) (887,233 ) 4,280,929 (4,320,928 ) Income tax expense 3 — 120 — 123 Net loss (3,697,545 ) (4,017,082 ) (887,353 ) 4,280,929 (4,321,051 ) Less: net loss attributable to noncontrolling interest — — — (623,506 ) (623,506 ) Net loss attributable to SandRidge Energy, Inc. $ (3,697,545 ) $ (4,017,082 ) $ (887,353 ) $ 4,904,435 $ (3,697,545 ) Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Year Ended December 31, 2014 Total revenues $ — $ 1,341,531 $ 217,367 $ (140 ) $ 1,558,758 Expenses Direct operating expenses — 467,175 16,854 (140 ) 483,889 General and administrative 331 118,249 4,285 — 122,865 Depreciation, depletion, amortization and accretion — 446,149 56,874 — 503,023 Impairment — 150,125 42,643 — 192,768 Gain on derivative contracts — (292,733 ) (41,278 ) — (334,011 ) Total expenses 331 888,965 79,378 (140 ) 968,534 (Loss) income from operations (331 ) 452,566 137,989 — 590,224 Equity earnings from subsidiaries 495,154 38,967 — (534,121 ) — Interest (expense) income, net (244,209 ) 100 — — (244,109 ) Other income (expense), net — 3,521 (31 ) — 3,490 Income before income taxes 250,614 495,154 137,958 (534,121 ) 349,605 Income tax (benefit) expense (2,671 ) — 378 — (2,293 ) Net income 253,285 495,154 137,580 (534,121 ) 351,898 Less: net income attributable to noncontrolling interest — — — 98,613 98,613 Net income attributable to SandRidge Energy, Inc. $ 253,285 $ 495,154 $ 137,580 $ (632,734 ) $ 253,285 Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Year Ended December 31, 2013 Total revenues $ — $ 1,675,481 $ 308,300 $ (393 ) $ 1,983,388 Expenses Direct operating expenses — 654,080 29,143 (393 ) 682,830 General and administrative 329 323,808 6,288 — 330,425 Depreciation, depletion, amortization and accretion — 581,435 85,210 — 666,645 Impairment — 15,038 11,242 — 26,280 Loss on derivative contracts — 24,702 22,421 — 47,123 Loss on sale of assets — 291,743 107,343 — 399,086 Total expenses 329 1,890,806 261,647 (393 ) 2,152,389 (Loss) income from operations (329 ) (215,325 ) 46,653 — (169,001 ) Equity earnings from subsidiaries (195,118 ) 3,075 — 192,043 — Interest (expense) income, net (271,193 ) 959 — — (270,234 ) Loss on extinguishment of debt (82,005 ) — — — (82,005 ) Other income (expense), net — 16,173 (3,728 ) — 12,445 (Loss) income before income taxes (548,645 ) (195,118 ) 42,925 192,043 (508,795 ) Income tax expense 5,244 — 440 — 5,684 Net (loss) income (553,889 ) (195,118 ) 42,485 192,043 (514,479 ) Less: net income attributable to noncontrolling interest — — — 39,410 39,410 Net (loss) income attributable to SandRidge Energy, Inc. $ (553,889 ) $ (195,118 ) $ 42,485 $ 152,633 $ (553,889 )
Condensed Consolidating Statements of Cash Flows of SandRidge Energy, Inc. and Wholly Owned Subsidiary Guarantors and Non-Guarantors	Condensed Consolidating Statements of Cash Flows Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Year Ended December 31, 2015 Net cash (used in) provided by operating activities $ (326,674 ) $ 524,313 $ 124,626 $ 51,272 $ 373,537 Cash flows from investing activities Capital expenditures for property, plant and equipment — (879,201 ) — — (879,201 ) Acquisition of assets — (216,943 ) — — (216,943 ) Other — 74,140 907 (18,543 ) 56,504 Net cash (used in) provided by investing activities — (1,022,004 ) 907 (18,543 ) (1,039,640 ) Cash flows from financing activities Proceeds from borrowings 2,065,000 — — — 2,065,000 Repayments of borrowings (939,466 ) — — — (939,466 ) Distributions to unitholders — — (158,629 ) 20,324 (138,305 ) Intercompany (advances) borrowings, net (475,618 ) 497,140 (21,522 ) — — Other (66,793 ) — 53,055 (53,053 ) (66,791 ) Net cash provided by (used in) financing activities 583,123 497,140 (127,096 ) (32,729 ) 920,438 Net increase (decrease) in cash and cash equivalents 256,449 (551 ) (1,563 ) — 254,335 Cash and cash equivalents at beginning of year 170,468 1,398 9,387 — 181,253 Cash and cash equivalents at end of year $ 426,917 $ 847 $ 7,824 $ — $ 435,588 Parent(1) Guarantors(1)(2) Non-Guarantors Eliminations(2) Consolidated (In thousands) Year Ended December 31, 2014 Net cash (used in) provided by operating activities $ (240,932 ) $ 641,181 $ 212,427 $ 8,438 $ 621,114 Cash flows from investing activities Capital expenditures for property, plant and equipment — (1,553,332 ) — — (1,553,332 ) Proceeds from sale of assets — 711,728 2,747 — 714,475 Other — 28,256 1,140 (47,780 ) (18,384 ) Net cash (used in) provided by investing activities — (813,348 ) 3,887 (47,780 ) (857,241 ) Cash flows from financing activities Distributions to unitholders — — (234,327 ) 40,520 (193,807 ) Repurchase of common stock (111,827 ) — — — (111,827 ) Intercompany (advances) borrowings, net (215,368 ) 215,373 (5 ) — — Other (66,910 ) (42,821 ) 19,260 (1,178 ) (91,649 ) Net cash (used in) provided by financing activities (394,105 ) 172,552 (215,072 ) 39,342 (397,283 ) Net (decrease) increase in cash and cash equivalents (635,037 ) 385 1,242 — (633,410 ) Cash and cash equivalents at beginning of year 805,505 1,013 8,145 — 814,663 Cash and cash equivalents at end of year $ 170,468 $ 1,398 $ 9,387 $ — $ 181,253 ____________________ (1) Net cash (used in) provided by operating activities for the Parent has decreased to correctly exclude $382.7 million in intercompany transactions, with a corresponding increase for Guarantors for this same line item. In addition, Intercompany (advances) borrowings, net for the Parent has increased to correctly include approximately $382.7 million of intercompany transactions, with a corresponding decrease for Guarantors for the same line item. The corrections did not result in any changes to consolidated net cash provided by operating activities or net cash used in financing activities. (2) Other investing activities for the Guarantor has increased to correctly exclude $193.8 million in noncontrolling interest distributions, with a corresponding decrease for Eliminations for this same line item. In addition, other financing activities for the Guarantor, has decreased to correctly exclude $193.8 million of noncontrolling interest distributions, with a corresponding increase for Eliminations for the same line item. The corrections did not result in any changes to consolidated net cash (used in) provided by investing activities or net cash used in financing activities. Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Year Ended December 31, 2013 Net cash (used in) provided by operating activities $ (239,026 ) $ 852,026 $ 254,723 $ 907 $ 868,630 Cash flows from investing activities Capital expenditures for property, plant and equipment — (1,496,731 ) — — (1,496,731 ) Proceeds from sale of assets — 2,566,742 17,373 — 2,584,115 Other — 89,606 3,197 (109,831 ) (17,028 ) Net cash used in investing activities — 1,159,617 20,570 (109,831 ) 1,070,356 Cash flows from financing activities Repayments of borrowings (1,115,500 ) — — — (1,115,500 ) Premium on debt redemption (61,997 ) — — — (61,997 ) Distributions to unitholders — — (299,675 ) 93,205 (206,470 ) Dividends paid—preferred (55,525 ) — — — (55,525 ) Intercompany borrowings (advances) , net 2,009,146 (2,018,212 ) 9,066 — — Other (31,821 ) 6,660 14,845 15,719 5,403 Net cash provided by (used in) financing activities 744,303 (2,011,552 ) (275,764 ) 108,924 (1,434,089 ) Net increase (decrease) in cash and cash equivalents 505,277 91 (471 ) — 504,897 Cash and cash equivalents at beginning of year 300,228 922 8,616 — 309,766 Cash and cash equivalents at end of year $ 805,505 $ 1,013 $ 8,145 $ — $ 814,663

Supplemental Information on O53

Supplemental Information on Oil and Natural Gas Producing Activities (Tables)	12 Months Ended
	Dec. 31, 2015
Reserve Quantities [Line Items]
Capitalized Costs Relating to Oil, Natural Gas and NGL Producing Activities	The Company’s capitalized costs for oil and natural gas activities consisted of the following (in thousands): December 31, 2015 2014 2013 Oil and natural gas properties Proved $ 12,529,681 $ 11,707,147 $ 10,972,816 Unproved 363,149 290,596 531,606 Total oil and natural gas properties 12,892,830 11,997,743 11,504,422 Less accumulated depreciation, depletion and impairment (11,149,888 ) (6,359,149 ) (5,762,969 ) Net oil and natural gas properties capitalized costs $ 1,742,942 $ 5,638,594 $ 5,741,453
Cost Incurred in Oil and Natural Gas Property Acquisition, Exploration, and Development	Costs incurred in oil and natural gas property acquisition, exploration and development activities which have been capitalized are summarized as follows (in thousands): Year Ended December 31, 2015 2014 2013 Acquisitions of properties Proved $ 35,376 $ 73,370 $ 21,130 Unproved 210,065 123,649 100,242 Exploration(1) 29,297 41,070 82,775 Development 571,562 1,288,395 1,131,269 Total cost incurred $ 846,300 $ 1,526,484 $ 1,335,416 ____________________ (1) Includes seismic costs of $7.1 million , $10.8 million and $6.7 million for 2015 , 2014 and 2013 , respectively.
Results of Operations for Oil, Natural Gas and NGL Producing Activities	The Company’s results of operations from oil and natural gas producing activities for each of the years 2015 , 2014 and 2013 are shown in the following table (in thousands): Year Ended December 31, 2015 2014(1) 2013 Revenues $ 707,434 $ 1,420,879 $ 1,820,278 Expenses Production costs 324,141 377,819 548,719 Depreciation and depletion 319,913 434,295 567,732 Accretion of asset retirement obligations 4,477 9,092 36,777 Impairment 4,473,787 164,779 — Total expenses 5,122,318 985,985 1,153,228 (Loss) income before income taxes (4,414,884 ) 434,894 667,050 Income tax expense (benefit)(2) 126 (2,852 ) (7,471 ) Results of operations for oil and natural gas producing activities (excluding corporate overhead and interest costs) $ (4,415,010 ) $ 437,746 $ 674,521 ____________________ (1) Total expenses increased by $164.8 million and benefit of income taxes decreased by $1.1 million to correctly include the impact of the ceiling test impairment incurred during the year ended December 31, 2014. (2) Reflects the Company’s effective tax rate for each period.
Summary of Changes in Estimated Oil, Natural Gas and NGL Reserves	The summary below presents changes in the Company’s estimated reserves for 2013 , 2014 and 2015 . Oil NGL Natural Gas (MBbls) (MBbls) (MMcf)(1) Proved developed and undeveloped reserves As of December 31, 2012 262,045 67,994 1,415,042 Revisions of previous estimates (13,969 ) 3,717 (53,432 ) Acquisitions of new reserves 43 13 363 Extensions and discoveries 40,570 18,686 359,918 Sales of reserves in place (131,769 ) (29,067 ) (228,229 ) Production (14,279 ) (2,291 ) (103,233 ) As of December 31, 2013(2) 142,641 59,052 1,390,429 Revisions of previous estimates (18,687 ) 11,103 167,589 Acquisitions of new reserves 1,009 441 12,527 Extensions and discoveries 37,603 27,500 467,185 Sales of reserves in place (25,659 ) (2,516 ) (163,800 ) Production (10,876 ) (3,794 ) (85,697 ) As of December 31, 2014(2) 126,031 91,786 1,788,233 Revisions of previous estimates (70,708 ) (37,384 ) (759,106 ) Acquisitions of new reserves 22,447 2,460 15,952 Extensions and discoveries 9,741 9,257 160,865 Production (9,600 ) (5,044 ) (92,104 ) As of December 31, 2015(2) 77,911 61,075 1,113,840 Proved developed reserves As of December 31, 2012 136,605 33,785 896,701 As of December 31, 2013 83,893 35,807 951,609 As of December 31, 2014 79,022 56,823 1,203,447 As of December 31, 2015 48,639 51,089 964,617 Proved undeveloped reserves As of December 31, 2012 125,440 34,209 518,341 As of December 31, 2013 58,748 23,245 438,820 As of December 31, 2014 47,009 34,963 584,786 As of December 31, 2015 29,272 9,986 149,223 ____________________ (1) Natural gas reserves are computed at 14.65 pounds per square inch absolute and 60 degrees Fahrenheit. (2) Includes proved reserves attributable to noncontrolling interests at December 31, 2015 , 2014 and 2013 as shown in the table below: December 31, 2015 2014 2013 Oil (MBbl) 7,004 11,027 13,569 NGL (MBbl) 3,694 4,761 4,737 Natural gas (MMcf) 50,508 70,833 69,693
Calculation of Weighted Average Per Unit Prices	The calculated weighted average per unit prices for the Company’s proved reserves and future net revenues were as follows: At December 31, 2015 2014 2013 Oil (per barrel) $ 45.29 $ 91.65 $ 95.67 NGL (per barrel) $ 12.68 $ 32.79 $ 31.40 Natural gas (per Mcf) $ 1.87 $ 3.61 $ 3.65
Standardized Measure of Discounted Future Cash Flows	The summary below presents the Company’s future net cash flows relating to proved oil, natural gas and NGL reserves based on the standardized measure in ASC Topic 932 (in thousands). At December 31, 2015 2014 2013 Future cash inflows from production $ 6,387,944 $ 21,022,320 $ 19,937,484 Future production costs (2,731,542 ) (6,499,366 ) (6,843,713 ) Future development costs(1) (838,945 ) (1,810,201 ) (2,546,680 ) Future income tax expenses (901 ) (3,223,740 ) (2,283,541 ) Undiscounted future net cash flows 2,816,556 9,489,013 8,263,550 10% annual discount (1,501,994 ) (5,401,261 ) (4,245,939 ) Standardized measure of discounted future net cash flows(2) $ 1,314,562 $ 4,087,752 $ 4,017,611 ____________________ (1) Includes abandonment costs. (2) Includes approximately $224.6 million , $643.3 million and $781.6 million attributable to noncontrolling interests at December 31, 2015 , 2014 and 2013 respectively.
Estimate of Changes in Standardized Measure of Discounted Future Net Cash Flows from Proved Reserves	The following table represents the Company’s estimate of changes in the standardized measure of discounted future net cash flows from proved reserves (in thousands): Present value as of December 31, 2012 $ 5,840,368 Changes during the year Revenues less production and other costs (1,271,559 ) Net changes in prices, production and other costs 271,566 Development costs incurred 474,275 Net changes in future development costs (207,729 ) Extensions and discoveries 1,406,102 Revisions of previous quantity estimates (296,418 ) Accretion of discount 711,385 Net change in income taxes 477,328 Purchases of reserves in-place 1,628 Sales of reserves in-place (3,172,187 ) Timing differences and other(1) (217,148 ) Net change for the year (1,822,757 ) Present value as of December 31, 2013(2) 4,017,611 Changes during the year Revenues less production and other costs (1,043,060 ) Net changes in prices, production and other costs 331,694 Development costs incurred 364,262 Net changes in future development costs (341,183 ) Extensions and discoveries 1,785,963 Revisions of previous quantity estimates (77,688 ) Accretion of discount 477,458 Net change in income taxes (256,371 ) Purchases of reserves in-place 50,958 Sales of reserves in-place (1,058,330 ) Timing differences and other(1) (163,562 ) Net change for the year 70,141 Present value as of December 31, 2014(2) 4,087,752 Changes during the year Revenues less production and other costs (383,293 ) Net changes in prices, production and other costs (3,813,465 ) Development costs incurred 217,596 Net changes in future development costs 273,437 Extensions and discoveries 230,055 Revisions of previous quantity estimates (1,354,778 ) Accretion of discount 512,483 Net change in income taxes 1,426,333 Purchases of reserves in-place 18,429 Sales of reserves in-place — Timing differences and other(1) 100,013 Net change for the year (2,773,190 ) Present value as of December 31, 2015(2) $ 1,314,562 ____________________ (1) The change in timing differences and other are related to revisions in the Company’s estimated time of production and development. (2) Includes approximately $224.6 million , $643.3 million and $781.6 million attributable to noncontrolling interests at December 31, 2015 , 2014 , and 2013 respectively.
Noncontrolling Interest
Reserve Quantities [Line Items]
Summary of Changes in Estimated Oil, Natural Gas and NGL Reserves	Includes proved reserves attributable to noncontrolling interests at December 31, 2015 , 2014 and 2013 as shown in the table below: December 31, 2015 2014 2013 Oil (MBbl) 7,004 11,027 13,569 NGL (MBbl) 3,694 4,761 4,737 Natural gas (MMcf) 50,508 70,833 69,693

Quarterly Financial Results (54

Quarterly Financial Results (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Results (Unaudited)	The Company’s operating results for each quarter of 2015 and 2014 are summarized below (in thousands, except per share data). First Quarter Second Quarter Third Quarter Fourth Quarter 2015 Total revenues $ 215,308 $ 229,607 $ 180,152 $ 143,642 Loss from operations(1)(2) $ (1,088,456 ) $ (1,535,083 ) $ (1,059,733 ) $ (959,406 ) Net loss(1)(2) $ (1,151,874 ) $ (1,588,731 ) $ (796,485 ) $ (783,961 ) Loss applicable to SandRidge Energy, Inc. common stockholders(1)(2) $ (1,045,834 ) $ (1,375,556 ) $ (649,526 ) $ (664,579 ) Loss applicable per share to SandRidge Energy, Inc. common stockholders(3) Basic $ (2.19 ) $ (2.78 ) $ (1.23 ) $ (1.13 ) Diluted $ (2.19 ) $ (2.78 ) $ (1.23 ) $ (1.13 ) 2014 Total revenues $ 443,056 $ 374,714 $ 394,107 $ 346,881 (Loss) income from operations(4)(5) $ (82,330 ) $ 42,079 $ 256,491 $ 373,984 Net (loss) income(4)(5) $ (142,406 ) $ (17,252 ) $ 197,499 $ 314,057 (Loss applicable) income available to SandRidge Energy, Inc. common stockholders(4)(5) $ (150,217 ) $ (46,775 ) $ 145,957 $ 254,295 (Loss applicable) income available per share to SandRidge Energy, Inc. common stockholders(3) Basic $ (0.31 ) $ (0.10 ) $ 0.30 $ 0.55 Diluted $ (0.31 ) $ (0.10 ) $ 0.27 $ 0.48 ____________________ (1) Includes impairment of $1.1 billion , $1.5 billion , $1.1 billion and $886.8 million for the first, second, third and fourth quarters, respectively. See Note 8 for further discussion of impairment. (2) Includes (gain) loss on derivative contracts of $(49.8) million , $33.0 million , $(42.2) million and $(14.0) million for the first, second, third and fourth quarters, respectively. (3) (Loss applicable) income available per share to common stockholders for each quarter is computed using the weighted-average number of shares outstanding during the quarter, while earnings per share for the fiscal year is computed using the weighted-average number of shares outstanding during the year. Thus, the sum of (loss applicable) income available per share to common stockholders for each of the four quarters may not equal the fiscal year amount. (4) Includes a full cost ceiling limitation impairment of $164.8 million in the first quarter and impairments of drilling assets of $3.1 million and $24.3 million in the second and fourth quarters, respectively. (5) Includes loss (gain) on derivative contracts of $42.5 million , $85.3 million , $(132.6) million and $(329.2) million for the first, second, third and fourth quarters, respectively.

Summary of Significant Accoun55

Summary of Significant Accounting Policies - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Mar. 21, 2016	Mar. 11, 2016	Oct. 31, 2015	Aug. 31, 2015	Jun. 30, 2015	Jun. 09, 2015
Significant Accounting Policies [Line Items]
Debt instrument, subjective acceleration clause, period	30 days
Capitalized costs	$ 846,300	$ 1,526,484	$ 1,335,416
Maximum reserves sold from cost center not expected to result in significant alteration (less than)	25.00%
Natural gas balancing liability	$ 1,500	1,400
Advertising and promotional costs	700	1,300	5,100
Internal Costs
Significant Accounting Policies [Line Items]
Capitalized costs	$ 45,100	55,400	74,700
Buildings | Minimum
Significant Accounting Policies [Line Items]
Property, plant and equipment, useful life	10 years
Buildings | Maximum
Significant Accounting Policies [Line Items]
Property, plant and equipment, useful life	39 years
Equipment | Minimum
Significant Accounting Policies [Line Items]
Property, plant and equipment, useful life	3 years
Equipment | Maximum
Significant Accounting Policies [Line Items]
Property, plant and equipment, useful life	30 years
Oil And Gas Unproved Properties
Significant Accounting Policies [Line Items]
Interest capitalized during period	$ 10,800	14,700	11,700
Midstream And Corporate Assets
Significant Accounting Policies [Line Items]
Interest capitalized during period	$ 3,300	$ 5,000	$ 4,900
8.125% Convertible Senior Notes due 2022
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate	8.125%
7.5% Convertible Senior Notes due 2023
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate	7.50%
Senior credit facility
Significant Accounting Policies [Line Items]
Line of credit facility, current borrowing capacity									$ 900,000
Secured Debt | 8.75% Senior Secured Notes Due 2020
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate	8.75%							8.75%
Convertible Debt | 8.125% Convertible Senior Notes due 2022
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate	8.125%	8.125%				8.125%	8.125%
Convertible Debt | 7.5% Convertible Senior Notes due 2023
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate	7.50%	7.50%				7.50%	7.50%
Restricted Stock Units
Significant Accounting Policies [Line Items]
Vesting period (in years)	4 years
June Amendment | Senior credit facility
Significant Accounting Policies [Line Items]
Line of credit facility, current borrowing capacity	$ 500,000
Subsequent Event | June Amendment | Senior credit facility
Significant Accounting Policies [Line Items]
Line of credit facility, current borrowing capacity					$ 340,000
Line of credit facility, target borrowing capacity				$ 500,000

Supplemental Cash Flow Inform56

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Supplemental Disclosure of Cash Flow Information
Cash paid for interest, net of amounts capitalized	$ (296,386)	$ (235,793)	$ (274,850)
Cash (paid) received for income taxes	(88)	1,928	(4,610)
Supplemental Disclosure of Noncash Investing and Financing Activities
Deposit on pending sale	0	0	(255,000)
Change in accrued capital expenditures	177,586	(55,557)	72,848
Equity issued for debt	(63,299)	0	0
Preferred stock dividends paid in common stock	(16,188)	0	0
Long-term debt issued, including derivative and net of discount, for asset acquisition and termination of gathering agreement	$ (50,310)	$ 0	$ 0

Acquisitions and Divestitures -

Acquisitions and Divestitures - Acquisitions (Details)	1 Months Ended		12 Months Ended
	Dec. 31, 2015USD ($)awell	Oct. 31, 2015USD ($)mi	Dec. 31, 2015USD ($)awell	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Aug. 31, 2015
Property, Plant and Equipment [Line Items]
Payments to acquire oil and gas property and equipment			$ 216,943,000	$ 18,384,000	$ 17,028,000
Fair value of assets acquired			701,615,000	1,608,889,000	1,423,883,000
Loss on termination of the gathering contract			$ 50,976,000	$ 0	$ 0
Pinon Gathering Company LLC
Property, Plant and Equipment [Line Items]
Payments to acquire oil and gas property and equipment		$ 48,000,000
Principal amount of debt issued related to acquisition		$ 78,000,000
Number of miles of gathering lines acquired | mi		370
Fair value of consideration paid for acquisition		$ 98,300,000
Loss on termination of the gathering contract		51,000,000
Rockies Properties | North Park Basin, Jackson County, Colorado
Property, Plant and Equipment [Line Items]
Payments to acquire oil and gas property and equipment	$ 191,100,000
Number acres acquired | a	135,000		135,000
Proceeds from sale of oil and natural gas properties	$ 3,100,000
Number of wells acquired | well	16		16
Oil and Gas Properties | Pinon Gathering Company LLC
Property, Plant and Equipment [Line Items]
Fair value of assets acquired		$ 47,300,000
Senior Notes | 8.75% Senior Notes due 2020
Property, Plant and Equipment [Line Items]
Long-term debt, fixed interest rate	8.75%	8.75%	8.75%	8.75%		8.75%

Acquisitions and Divestitures58

Acquisitions and Divestitures - Divestitures (Details) - Disposal Group, Disposed of by Sale, Not Discontinued Operations - USD ($)	Feb. 25, 2014	Feb. 26, 2013	Dec. 31, 2013	Mar. 31, 2015	Dec. 31, 2014
Gulf Properties
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and natural gas properties	$ 702,600,000
Guarantee period for certain plugging and abandonment obligations (up to)	1 year
Contingent liability equal to fair value of guarantees recorded as part of sale	$ 9,400,000				$ 5,100,000
Restricted deposits previously held in escrow, cash received				$ 12,000,000
Loss on sale of oil and gas property	0
Permian Properties
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and natural gas properties		$ 2,600,000,000
Loss on sale of oil and gas property			$ 398,900,000
Permian Properties | Non-controlling Interest
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Loss on sale of oil and gas property			$ 71,700,000
Asset Retirement Obligations | Gulf Properties
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Asset retirement obligations assumed	$ 366,000,000

Acquisitions and Divestitures59

Acquisitions and Divestitures - Gulf Properties Disposal - Revenue and Expense Information (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues	$ 143,642	$ 180,152	$ 229,607	$ 215,308	$ 346,881	$ 394,107	$ 374,714	$ 443,056	$ 768,709	$ 1,558,758	$ 1,983,388
Expenses									$ 5,411,387	968,534	2,152,389
Gulf Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues										90,920	627,236
Expenses										$ 63,674	$ 491,991

Acquisitions and Divestitures60

Acquisitions and Divestitures - Permian Properties Disposal - Revenue and Expense Information (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues	$ 143,642	$ 180,152	$ 229,607	$ 215,308	$ 346,881	$ 394,107	$ 374,714	$ 443,056	$ 768,709	$ 1,558,758	$ 1,983,388
Direct operating expenses									$ 375,354	$ 483,889	682,830
Permian Properties | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues											68,027
Direct operating expenses											$ 17,453

Variable Interest Entities - Ro

Variable Interest Entities - Royalty Trusts - Common and Subordinated Units Outstanding (Details) - shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Mississippian Trust I
Variable Interest Entity [Line Items]
Total outstanding common units (in shares)	28,000,000	28,000,000
Total outstanding subordinated units (in shares)	0	0
Permian Trust
Variable Interest Entity [Line Items]
Total outstanding common units (in shares)	39,375,000	39,375,000
Total outstanding subordinated units (in shares)	13,125,000	13,125,000
Mississippian Trust II
Variable Interest Entity [Line Items]
Total outstanding common units (in shares)	37,293,750	37,293,750
Total outstanding subordinated units (in shares)	12,431,250	12,431,250

Variable Interest Entities - 62

Variable Interest Entities - Royalty Trusts - Ownership Interest (Details)	Dec. 31, 2015	Dec. 31, 2014
Mississippian Trust I
Variable Interest Entity [Line Items]
Beneficial interest owned by Company	26.90%	26.90%
Permian Trust
Variable Interest Entity [Line Items]
Beneficial interest owned by Company	25.00%	25.00%
Mississippian Trust II
Variable Interest Entity [Line Items]
Beneficial interest owned by Company	37.60%	37.60%

Variable Interest Entities - Na

Variable Interest Entities - Narrative (Details)	12 Months Ended
	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Oct. 31, 2015mi	Mar. 31, 2014
Variable Interest Entity [Line Items]
Proceeds from the sale of royalty trust units	$ 0	$ 22,119,000	$ 28,985,000
Pinon Gathering Company LLC
Variable Interest Entity [Line Items]
Number of miles of gathering lines acquired | mi				370
Royalty Trusts
Variable Interest Entity [Line Items]
Percentage of royalty interest conveyed to company at trust termination	50.00%
Percentage of royalty interest sold at trust termination	50.00%
Percentage of subordinated units to total units	25.00%
Percentage of cash available in excess of target distribution paid for incentive distribution	50.00%
Conversion ratio of Royalty Trust subordinated unit to common units	1
Outstanding balance under loan commitment	$ 0	0
Noncontrolling interest in VIEs	510,200,000	1,300,000,000
Proceeds from the sale of royalty trust units		22,100,000	$ 29,000,000
Total liabilities	$ 1,060,000	$ 2,852,000
Grey Ranch Plant, L.P
Variable Interest Entity [Line Items]
Beneficial interest owned by Company			50.00%
Noncontrolling interest, ownership percentage by noncontrolling owners			50.00%
Noncontrolling interest, decrease from redemptions percentage					50.00%
Grey Ranch Plant Genpar, LLC (Genpar)
Variable Interest Entity [Line Items]
Beneficial interest owned by Company			50.00%
Noncontrolling interest, decrease from redemptions percentage					50.00%
Percentage ownership of another VIE			1.00%
Total liabilities			$ 0

Variable Interest Entities - 64

Variable Interest Entities - Royalty Trusts - Distributions (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Variable Interest Entity [Line Items]
Distributions to third-party unitholders	$ 138,305	$ 193,807	$ 206,470
Royalty Trusts
Variable Interest Entity [Line Items]
Total distributions	158,632	234,326	299,674
Distributions to third-party unitholders	$ 138,305	$ 193,807	$ 206,470

Variable Interest Entities - 65

Variable Interest Entities - Royalty Trusts - Assets and Liabilities Included in Consolidated Balance Sheets (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Variable Interest Entity [Line Items]
Cash and cash equivalents	$ 435,588	$ 181,253	$ 814,663	$ 309,766
Accounts receivable	127,387	330,077
Derivative contracts	84,349	291,414
Total current assets	674,088	831,918
Investment in royalty interests	12,892,830	11,997,743	11,504,422
Less: accumulated depletion and impairment	(11,149,888)	(6,359,149)	(5,762,969)
Net oil and natural gas properties capitalized costs	1,742,942	5,638,594	$ 5,741,453
Accounts payable and accrued expenses	428,417	683,392
Royalty Trusts
Variable Interest Entity [Line Items]
Cash and cash equivalents	7,824	9,387
Accounts receivable	4,457	17,660
Derivative contracts	0	6,589
Total current assets	12,281	33,636
Investment in royalty interests	1,325,942	1,325,942
Less: accumulated depletion and impairment	(1,248,957)	(284,094)
Net oil and natural gas properties capitalized costs	76,985	1,041,848
Total assets	89,266	1,075,484
Accounts payable and accrued expenses	1,060	2,852
Total liabilities	$ 1,060	$ 2,852

Variable Interest Entities - 66

Variable Interest Entities - Royalty Trusts - Assets and Liabilities Included in Consolidated Balance Sheets (Additional Information) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Variable Interest Entity [Line Items]
Cumulative full cost ceiling limitation impairment charges	$ 8,200	$ 3,700
Royalty Trusts
Variable Interest Entity [Line Items]
Reserves for future expenses	3	3
Cumulative full cost ceiling limitation impairment charges	$ 976.2	$ 42.3

Variable Interest Entities - PG

Variable Interest Entities - PGC - Amounts due to/from the Company (Details) - Pinon Gathering Company LLC $ in Thousands	Dec. 31, 2014USD ($)
Variable Interest Entity [Line Items]
Accounts receivable due from PGC	$ 1,141
Accounts payable due to PGC	$ 4,163

Fair Value Measurements - Signi

Fair Value Measurements - Significant Unobservable Inputs - Derivative Contracts (Details) - Natural gas basis swaps - Fair Value Measurements Level 3 $ in Thousands	Dec. 31, 2015USD ($)$ / Mcf	Dec. 31, 2014USD ($)$ / Mcf
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair value | $	$ (1,748)	$ 350
Minimum
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative, forward price (usd/mcf)	(0.06)	(0.03)
Maximum
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative, forward price (usd/mcf)	(0.28)	(0.38)
Weighted Average
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative, forward price (usd/mcf)	(0.22)	(0.29)

Fair Value Measurements - Sig69

Fair Value Measurements - Significant Unobservable Inputs - Long Term Debt Conversion Feature (Details) - Long-term debt holder conversion feature - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Fair Value	$ 29,355	$ 0
Fair Value Measurements Level 3
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Fair Value	$ 29,355
Minimum | Fair Value Measurements Level 3
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Hazard rate	114.00%
Maximum | Fair Value Measurements Level 3
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Hazard rate	135.20%
Weighted Average | Fair Value Measurements Level 3
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Hazard rate	119.20%

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Fair Value Assets And Liabilities Measured On Recurring Basis
Commodity derivative contracts, assets, net of offset	$ 84,349	$ 338,417
Commodity derivative contracts, liabilities, net of offset	573	0
Fair Value, Measurements, Recurring
Fair Value Assets And Liabilities Measured On Recurring Basis
Netting adjustment, assets	(1,175)	0
Commodity derivative contracts, assets, net of offset	84,349	338,417
Investments	10,106	11,106
Assets measured at fair value	94,455	349,523
Guarantee		5,104
Netting adjustments, liabilities	(1,175)	0
Commodity derivative contracts, liabilities, net of offset	573
Liabilities measured at fair value	32,869	5,104
Fair Value, Measurements, Recurring | Long-term debt holder conversion feature
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative liability, not subject to netting	29,355
Fair Value, Measurements, Recurring | Mandatory prepayment feature - PGC Senior Secured Notes
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative liability, not subject to netting	2,941
Fair Value, Measurements, Recurring | Fair Value Measurements Level 1
Fair Value Assets And Liabilities Measured On Recurring Basis
Commodity derivative contracts, assets, before netting	0	0
Investments	10,106	11,106
Assets measured at fair value	10,106	11,106
Guarantee		0
Commodity derivative contracts, liabilities, before netting	0
Liabilities measured at fair value	0	0
Fair Value, Measurements, Recurring | Fair Value Measurements Level 1 | Long-term debt holder conversion feature
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative liability, not subject to netting	0
Fair Value, Measurements, Recurring | Fair Value Measurements Level 1 | Mandatory prepayment feature - PGC Senior Secured Notes
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative liability, not subject to netting	0
Fair Value, Measurements, Recurring | Fair Value Measurements Level 2
Fair Value Assets And Liabilities Measured On Recurring Basis
Commodity derivative contracts, assets, before netting	85,524	338,067
Investments	0	0
Assets measured at fair value	85,524	338,067
Guarantee		0
Commodity derivative contracts, liabilities, before netting	0
Liabilities measured at fair value	2,941	0
Fair Value, Measurements, Recurring | Fair Value Measurements Level 2 | Long-term debt holder conversion feature
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative liability, not subject to netting	0
Fair Value, Measurements, Recurring | Fair Value Measurements Level 2 | Mandatory prepayment feature - PGC Senior Secured Notes
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative liability, not subject to netting	2,941
Fair Value, Measurements, Recurring | Fair Value Measurements Level 3
Fair Value Assets And Liabilities Measured On Recurring Basis
Commodity derivative contracts, assets, before netting	0	350
Investments	0	0
Assets measured at fair value	0	350
Guarantee		5,104
Commodity derivative contracts, liabilities, before netting	1,748
Liabilities measured at fair value	31,103	$ 5,104
Fair Value, Measurements, Recurring | Fair Value Measurements Level 3 | Long-term debt holder conversion feature
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative liability, not subject to netting	29,355
Fair Value, Measurements, Recurring | Fair Value Measurements Level 3 | Mandatory prepayment feature - PGC Senior Secured Notes
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative liability, not subject to netting	$ 0

Fair Value Measurements - Recon

Fair Value Measurements - Reconciliation of Fair Value Measurements for Commodity Derivative Contracts (Details) - Commodity derivatives contracts - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Level 3 Fair Value Measurements - Commodity Derivative Contracts
Beginning balance	$ 350	$ 0	$ (512)
Loss on commodity derivative contracts	(350)	0	(133)
Purchases	(1,748)	350	0
Settlements paid	0	0	645
Level 3 commodity derivative contracts at December 31	$ (1,748)	$ 350	$ 0

Fair Value Measurements - Rec72

Fair Value Measurements - Reconciliation of Fair Value Measurements for Long-Term Debt Holder Conversion Feature (Details) - Long-term debt holder conversion feature $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
Level 3 Fair Value Measurements - Long-Term Debt Holder Conversion Feature
Beginning balance	$ 0
Issuances	31,200
Gain on derivative holder conversion feature	10,198
Conversions	(12,043)
Ending balance	$ 29,355

Fair Value Measurements - Rec73

Fair Value Measurements - Reconciliation of Fair Value Measurements for Guarantee (Details) - Guarantee - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Level 3 Fair Value Measurements - Guarantee
Beginning balance	$ 5,104	$ 0
Issuances	0	9,446
Loss on guarantee	0	(4,342)
Settlements	(5,104)	0
Ending balance	$ 0	$ 5,104

Fair Value Measurements - Estim

Fair Value Measurements - Estimated Fair Value and Carrying Value of Senior Notes (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Carrying Value	$ 3,631,506	$ 3,195,436
Secured Debt | 8.75% Senior Secured Notes Due 2020
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Carrying Value	1,301,098	0
Secured Debt | Fair Value Measurements Level 2 | 8.75% Senior Secured Notes Due 2020
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Fair Value	403,098	0
Senior Notes | 8.75% Senior Notes due 2020
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Carrying Value	392,666	445,402
Senior Notes | 7.5% Senior Notes due 2021
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Carrying Value	759,711	1,178,486
Senior Notes | 8.125% Senior Notes due 2022
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Carrying Value	527,737	750,000
Senior Notes | 7.5% Senior Notes due 2023
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Carrying Value	541,572	821,548
Senior Notes | Fair Value Measurements Level 2 | 8.75% Senior Notes due 2020
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Fair Value	39,740	303,750
Senior Notes | Fair Value Measurements Level 2 | 7.5% Senior Notes due 2021
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Fair Value	79,812	752,000
Senior Notes | Fair Value Measurements Level 2 | 8.125% Senior Notes due 2022
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Fair Value	57,749	472,500
Senior Notes | Fair Value Measurements Level 2 | 7.5% Senior Notes due 2023
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Fair Value	58,799	519,750
Convertible Debt | 8.125% Convertible Senior Notes due 2022
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Carrying Value	82,294	0
Convertible Debt | 7.5% Convertible Senior Notes due 2023
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Carrying Value	26,428	0
Convertible Debt | Fair Value Measurements Level 2 | 8.125% Convertible Senior Notes due 2022
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Fair Value	44,199	0
Convertible Debt | Fair Value Measurements Level 2 | 7.5% Convertible Senior Notes due 2023
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Fair Value	$ 15,125	$ 0

Fair Value Measurements - Est75

Fair Value Measurements - Estimated Fair Value and Carrying Value of Senior Notes (Additional Information) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Oct. 31, 2015	Aug. 31, 2015	Jun. 30, 2015
8.125% Convertible Senior Notes due 2022
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate	8.125%
7.5% Convertible Senior Notes due 2023
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate	7.50%
Secured Debt | 8.75% Senior Secured Notes Due 2020
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate	8.75%				8.75%
Debt maturity date	2,020
Embedded derivative, fair value	$ 2,941		$ 2,800
Long term debt, discount	$ 29,842		$ 30,500
Senior Notes | 8.75% Senior Notes due 2020
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate	8.75%	8.75%	8.75%	8.75%
Debt maturity date	2,020	2,020
Long term debt, discount	$ 3,269	$ 4,598
Senior Notes | 7.5% Senior Notes due 2021
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate	7.50%	7.50%	7.50%	7.50%
Debt maturity date	2,021	2,021
Long term debt, premium	$ 1,944	$ 3,486
Senior Notes | 8.125% Senior Notes due 2022
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate	8.125%	8.125%	8.125%	8.125%
Debt maturity date	2,022	2,022
Senior Notes | 7.5% Senior Notes due 2023
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate	7.50%	7.50%	7.50%	7.50%
Debt maturity date	2,023	2,023
Long term debt, discount	$ 1,989	$ 3,452
Convertible Debt | 8.125% Convertible Senior Notes due 2022
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate	8.125%	8.125%	8.125%	8.125%
Debt maturity date	2,022	2,022
Embedded derivative, fair value	$ 21,874
Long term debt, discount	$ 180,751
Convertible Debt | 7.5% Convertible Senior Notes due 2023
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate	7.50%	7.50%	7.50%	7.50%
Debt maturity date	2,023	2,023
Embedded derivative, fair value	$ 7,481
Long term debt, discount	$ 59,549

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2015	Oct. 31, 2015	Aug. 31, 2015	Jun. 30, 2015
Gulf Properties
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Fair value inputs, probability of default	3.71%
Secured Debt | 8.75% Senior Secured Notes Due 2020
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Debt instrument, face amount		$ 1,300,000,000	$ 78,000,000		$ 1,250,000,000
Long-term debt, fixed interest rate		8.75%			8.75%
Senior Notes | 8.75% Senior Notes due 2020
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate	8.75%	8.75%	8.75%	8.75%
Mandatory prepayment feature, threshold amount of outstanding principal amount of senior notes		$ 100,000,000
Fair Value Measurements Level 3 | Gulf Properties
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Estimate of future payments for plugging and abandonment	$ 372,000,000

Accounts Receivable - Summary o

Accounts Receivable - Summary of Accounts Receivable (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Receivables [Abstract]
Oil, natural gas and NGL sales	$ 61,140	$ 139,848
Joint interest billing	60,403	170,937
Oil and natural gas services	2,417	21,436
Other	8,274	4,939
Accounts receivable, gross	132,234	337,160
Less: allowance for doubtful accounts	(4,847)	(7,083)	$ (11,061)	$ (5,635)
Total accounts receivable, net	$ 127,387	$ 330,077

Accounts Receivable - Balance a

Accounts Receivable - Balance and Activity in Allowance for Doubtful Accounts (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Allowance for Doubtful Accounts
Beginning balance	$ 7,083	$ 11,061	$ 5,635
Additions charged to costs and expenses	1,320	818	5,497
Deductions	(3,556)	(4,796)	(71)
Ending balance	$ 4,847	$ 7,083	$ 11,061

Accounts Receivable - Balance79

Accounts Receivable - Balance and Activity in Allowance for Doubtful Accounts (Additional Information) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Accounts, Notes, Loans and Financing Receivable [Line Items]
Additions charged to costs and expenses	$ 1,320	$ 818	$ 5,497
Customer in Bankruptcy
Accounts, Notes, Loans and Financing Receivable [Line Items]
Additions charged to costs and expenses			$ 2,700

Property, Plant and Equipment80

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Oil and natural gas properties
Proved	$ 12,529,681	$ 11,707,147	$ 10,972,816
Unproved	363,149	290,596	531,606
Total oil and natural gas properties	12,892,830	11,997,743	11,504,422
Less: accumulated depreciation, depletion and impairment	(11,149,888)	(6,359,149)	(5,762,969)
Net oil and natural gas properties capitalized costs	1,742,942	5,638,594	$ 5,741,453
Land	14,260	16,300
Non-oil and natural gas equipment	373,687	602,392
Buildings and structures	227,673	263,191
Total	615,620	881,883
Less accumulated depreciation and amortization	(123,860)	(305,420)
Other property, plant and equipment, net	491,760	576,463
Total property, plant and equipment, net	$ 2,234,702	$ 6,215,057

Property, Plant and Equipment81

Property, Plant and Equipment (Additional Information) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Oil and gas proved properties
Property, Plant and Equipment [Line Items]
Cumulative capitalized interest	$ 48.9	$ 38.1
Non-oil and natural gas equipment
Property, Plant and Equipment [Line Items]
Cumulative capitalized interest	4.3	4.3
Building and structures
Property, Plant and Equipment [Line Items]
Cumulative capitalized interest	$ 20.4	$ 17.1

Property, Plant and Equipment -

Property, Plant and Equipment - Narrative (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2014USD ($)	Dec. 31, 2015USD ($)$ / Boe	Dec. 31, 2014USD ($)company$ / Boe	Dec. 31, 2013USD ($)company$ / Boe	Jun. 30, 2015USD ($)	May. 31, 2015well	Jun. 30, 2014USD ($)well
Property, Plant and Equipment [Line Items]
Cumulative full cost ceiling limitation impairment charges		$ 8,200,000,000	$ 3,700,000,000
Full cost ceiling impairments	$ 164,800,000	$ 4,500,000,000	$ 164,800,000	$ 0
Average depreciation and depletion rate (usd per Boe) | $ / Boe		10.67	15	16.81
Net value of assets held for sale		$ 491,760,000	$ 576,463,000
Loss on sale of assets		$ 1,491,000	$ 10,000	$ 399,086,000
Number of parties to agreements | company			2	2
Period during which target number of wells should be drilled for the carry commitment to be reduced				12 months
Expected completion of evaluation activities on majority of unproved properties		10 years
Repsol
Property, Plant and Equipment [Line Items]
Drilling carry received or billed			$ 205,600,000
Atinum and Repsol
Property, Plant and Equipment [Line Items]
Drilling carry received or billed				$ 408,000,000
Repsol
Property, Plant and Equipment [Line Items]
Minimum net wells | well							484
Net wells | well						453
Costs incurred toward satisfaction of obligation		$ 16,100,000
Repsol | Potential Drilling Carry Costs
Property, Plant and Equipment [Line Items]
Repsol's future drilling and completion costs, per well							$ 1,000,000
Future drilling and completion costs		31,000,000					$ 75,000,000
Drilling and Oil Field Services
Property, Plant and Equipment [Line Items]
Net value of assets held for sale		16,000,000			$ 20,000,000
Loss on sale of assets		$ 3,500,000

Property, Plant and Equipment83

Property, Plant and Equipment - Capitalized Costs of Unproved Properties Excluded from Amortization (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Property, Plant and Equipment [Abstract]
Property acquisition, cumulative	$ 362,803			$ 80,639
Property acquisition	197,849	$ 70,304	$ 14,011
Exploration, cumulative	34,988			339
Exploration	10,698	6,263	17,688
Total costs incurred, cumulative	397,791			$ 80,978
Total costs incurred	$ 208,547	$ 76,567	$ 31,699

Property, Plant and Equipment84

Property, Plant and Equipment - Capitalized Costs of Unproved Properties Excluded from Amortization (Additional Information) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Abstract]
Pipe inventory costs, cumulative	$ 34.7
Pipe inventory costs, period costs	$ 10.5	$ 6.2	$ 18

Impairment - Narrative (Details

Impairment - Narrative (Details)	3 Months Ended							12 Months Ended
	Dec. 31, 2015USD ($)property	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Jun. 30, 2014USD ($)	Mar. 31, 2014USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Full cost ceiling impairments							$ 164,800,000	$ 4,500,000,000	$ 164,800,000	$ 0
Asset impairment charges	$ 886,800,000	$ 1,100,000,000	$ 1,500,000,000	$ 1,100,000,000				4,534,689,000	192,768,000	26,280,000
Net value of assets held for sale	$ 491,760,000				$ 576,463,000			491,760,000	576,463,000
Number of properties held for sale | property	1
Drilling and Oil Field Services
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Net value of assets held for sale	$ 16,000,000		$ 20,000,000					16,000,000
Drilling and Oilfield Services Assets - Permian Region
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges									24,300,000
Drilling Assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges					$ 24,300,000	$ 3,100,000		37,600,000	3,100,000	11,100,000
Gas Treating Plants and other Midstream Assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges								7,100,000	$ 600,000	12,200,000
Buildings
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges								$ 15,400,000
Corporate Asset
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges										$ 2,900,000

Other Assets (Details)

Other Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Debt issuance costs, net of amortization	$ 72,259	$ 56,445
Deferred tax asset	0	95,843
Investments	10,106	11,106
Other	0	1,853
Total other assets	$ 82,365	$ 165,247

Accounts Payable and Accrued 87

Accounts Payable and Accrued Expenses (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Payables and Accruals [Abstract]
Accounts payable and other accrued expenses	$ 231,697	$ 392,500
Accrued interest	73,320	79,704
Production payable	55,260	120,573
Payroll and benefits	42,728	44,496
Convertible perpetual preferred stock dividends	21,572	11,072
Drilling advances	2,295	33,195
Related party	1,545	1,852
Total accounts payable and accrued expenses	$ 428,417	$ 683,392

Construction Contract - Narrati

Construction Contract - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Jun. 30, 2013
Construction Contracts [Line Items]
Construction contract revenue	$ 0	$ 0	$ 23,349
Construction contract costs	$ 0	$ 0	23,349
Transmission Expansion Projects
Construction Contracts [Line Items]
Construction contract price				$ 23,300
Construction contract revenue			23,300
Construction contract costs			$ 23,300

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Senior credit facility	$ 0	$ 0
Total debt	3,631,506	3,195,436
Less: current maturities of long-term debt	0	0
Long-term debt	3,631,506	3,195,436
Secured Debt | 8.75% Senior Secured Notes due 2020, including mandatory prepayment feature liabilities of $2,941, and net of $29,842 discount
Debt Instrument [Line Items]
Total debt	1,301,098	0
Senior Notes | 8.75% Senior Notes due 2020, net of $3,269 and $4,598 discount, respectively
Debt Instrument [Line Items]
Total debt	392,666	445,402
Senior Notes | 7.5% Senior Notes due 2021, including a premium of $1,944 and $3,486, respectively
Debt Instrument [Line Items]
Total debt	759,711	1,178,486
Senior Notes | 8.125% Senior Notes due 2022
Debt Instrument [Line Items]
Total debt	527,737	750,000
Senior Notes | 7.5% Senior Notes due 2023, net of $1,989 and $3,452 discount, respectively
Debt Instrument [Line Items]
Total debt	541,572	821,548
Convertible Debt | 8.125% Convertible Senior Notes due 2022, including holder conversion feature liabilities of $21,874, and net of $180,751 discount
Debt Instrument [Line Items]
Total debt	82,294	0
Convertible Debt | 7.5% Convertible Senior Notes due 2023, including holder conversion feature liabilities of $7,481, and net of $59,549 discount
Debt Instrument [Line Items]
Total debt	$ 26,428	$ 0

Long-Term Debt (Additional Info

Long-Term Debt (Additional Information) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Oct. 31, 2015	Aug. 31, 2015	Jun. 30, 2015
8.125% Convertible Senior Notes due 2022, including holder conversion feature liabilities of $21,874, and net of $180,751 discount
Debt Instrument [Line Items]
Long-term debt, fixed interest rate	8.125%
7.5% Convertible Senior Notes due 2023, including holder conversion feature liabilities of $7,481, and net of $59,549 discount
Debt Instrument [Line Items]
Long-term debt, fixed interest rate	7.50%
Secured Debt | 8.75% Senior Secured Notes Due 2020
Debt Instrument [Line Items]
Debt maturity date	2,020
Long-term debt, fixed interest rate	8.75%				8.75%
Long term debt, discount	$ 29,842		$ 30,500
Embedded derivative, fair value	$ 2,941		$ 2,800
Senior Notes | 8.75% Senior Notes due 2020, net of $3,269 and $4,598 discount, respectively
Debt Instrument [Line Items]
Debt maturity date	2,020	2,020
Long-term debt, fixed interest rate	8.75%	8.75%	8.75%	8.75%
Long term debt, discount	$ 3,269	$ 4,598
Senior Notes | 7.5% Senior Notes due 2021, including a premium of $1,944 and $3,486, respectively
Debt Instrument [Line Items]
Debt maturity date	2,021	2,021
Long-term debt, fixed interest rate	7.50%	7.50%	7.50%	7.50%
Long term debt, premium	$ 1,944	$ 3,486
Senior Notes | 8.125% Senior Notes due 2022
Debt Instrument [Line Items]
Debt maturity date	2,022	2,022
Long-term debt, fixed interest rate	8.125%	8.125%	8.125%	8.125%
Senior Notes | 7.5% Senior Notes due 2023, net of $1,989 and $3,452 discount, respectively
Debt Instrument [Line Items]
Debt maturity date	2,023	2,023
Long-term debt, fixed interest rate	7.50%	7.50%	7.50%	7.50%
Long term debt, discount	$ 1,989	$ 3,452
Convertible Debt | 8.125% Convertible Senior Notes due 2022, including holder conversion feature liabilities of $21,874, and net of $180,751 discount
Debt Instrument [Line Items]
Debt maturity date	2,022	2,022
Long-term debt, fixed interest rate	8.125%	8.125%	8.125%	8.125%
Long term debt, discount	$ 180,751
Embedded derivative, fair value	$ 21,874
Convertible Debt | 7.5% Convertible Senior Notes due 2023, including holder conversion feature liabilities of $7,481, and net of $59,549 discount
Debt Instrument [Line Items]
Debt maturity date	2,023	2,023
Long-term debt, fixed interest rate	7.50%	7.50%	7.50%	7.50%
Long term debt, discount	$ 59,549
Embedded derivative, fair value	$ 7,481

Long-Term Debt - Narrative (Det

Long-Term Debt - Narrative (Details) $ / shares in Units, shares in Millions	Jun. 10, 2015USD ($)	Oct. 31, 2015USD ($)	Aug. 31, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2013USD ($)$ / PrincipalAmount	Jun. 30, 2015USD ($)shares	Dec. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Oct. 16, 2015USD ($)	Aug. 13, 2015USD ($)	Jun. 09, 2015USD ($)
Debt Instrument [Line Items]
Write off of debt issuance costs							$ 7,108,000	$ 0	$ 0
Reduction in borrowing base for every $1 of junior lien debt incurred	$ 0.25
Senior credit facility outstanding amount							$ 0	0
Common stock issued for debt (in shares) | shares							92.8
Aggregate Principle of Notes Converted							$ 63,299,000	0	0
Gain (loss) on extinguishment of debt							641,131,000	$ 0	$ (82,005,000)
Aggregate cash payments for accrued interest and early conversion of debt							30,500,000
Long term debt maturing in 2020							1,700,000,000
Conversion of Senior Notes to Common Stock
Debt Instrument [Line Items]
Write off of debt issuance costs							5,200,000
Gain (loss) on extinguishment of debt						$ 17,900,000	$ 6,100,000
Repurchase of Senior Notes
Debt Instrument [Line Items]
Write off of debt issuance costs		$ 1,200,000	$ 3,200,000
Gain (loss) on extinguishment of debt		68,700,000	152,000,000		$ (82,000,000)
Conversion of Senior Notes to Convertible Debt
Debt Instrument [Line Items]
Write off of debt issuance costs		4,000,000	4,000,000
Gain (loss) on extinguishment of debt		$ 207,400,000	$ 189,000,000
8.125% Convertible Senior Notes due 2022
Debt Instrument [Line Items]
Long-term debt, fixed interest rate							8.125%
7.5% Convertible Senior Notes due 2023
Debt Instrument [Line Items]
Long-term debt, fixed interest rate							7.50%
Senior credit facility
Debt Instrument [Line Items]
Covenant, Ratio of secured debt to EBITDA, maximum												2.25
Covenant, Ratio of EBITDA to interest expense at Mar 2015												2
Covenant, Ratio of EBITDA to interest expense at Jun 2015												2
Covenant, Ratio of EBITDA to interest expense at Sep 2015												1.75
Covenant, Ratio of EBITDA to interest expense at Dec 2015												1.50
Covenant, Ratio of EBITDA to interest expense at Mar 2016												1.50
Covenant, Ratio of EBITDA to interest expense at Jun 2016												1.50
Covenant, Ratio of EBITDA to interest expense at Sep 2016												1.50
Covenant, Ratio of EBITDA to interest expense at Dec 2016												2
Current assets to current liabilities, ratio minimum												1
Covenant, Ratio of total net debt to EBITDA at Jun 2016												6.25
Covenant, Ratio of total net debt to EBITDA at Sep 2016												6
Covenant, Ratio of total net debt to EBITDA at Dec 2016												6
Covenant, Ratio of total net debt to EBITDA at Mar 2017												5.50
Covenant, Ratio of total net debt to EBITDA at Jun 2017												5.50
Covenant, Ratio of total net debt to EBITDA at Sep 2017												5
Covenant, Ratio of total net debt to EBITDA at Dec 2017												5
Covenant, Ratio of total net debt to EBITDA at Mar 2018												4.50
Line of credit facility, current borrowing capacity												$ 900,000,000
Line of credit facility, letters of credit outstanding							$ 11,000,000
Senior credit facility | August 2015 Amendment
Debt Instrument [Line Items]
Allowed repurchases of outstanding debt										$ 275,000,000	$ 200,000,000
Senior credit facility | June Amendment
Debt Instrument [Line Items]
Covenant, Ratio of secured debt to EBITDA, maximum							2
Current assets to current liabilities, ratio minimum							1
Line of credit facility, minimum collateral amount of proved oil and gas reserves representing the discounted present value of reserves used in borrowing base determination	80.00%
Line of credit facility maximum borrowings capacity	$ 1,000,000,000
Line of credit facility, current borrowing capacity							$ 500,000,000
Write off of debt issuance costs	4,900,000
Additional aggregate principal indebtedness permitted (less than)	$ 1,750,000,000
Senior credit facility | June Amendment | Maximum
Debt Instrument [Line Items]
Line of credit facility, unused capacity, commitment fee percentage	0.50%
Senior credit facility | June Amendment | London Interbank Offered Rate (LIBOR) | Minimum
Debt Instrument [Line Items]
Line of credit facility, basis spread on variable rate	1.75%
Senior credit facility | June Amendment | London Interbank Offered Rate (LIBOR) | Maximum
Debt Instrument [Line Items]
Line of credit facility, basis spread on variable rate	2.75%
Senior credit facility | June Amendment | Federal Funds
Debt Instrument [Line Items]
Line of credit facility, basis spread on variable rate	0.50%
Senior credit facility | June Amendment | One-Month Eurodollar Rate
Debt Instrument [Line Items]
Line of credit facility, basis spread on variable rate	1.00%
Senior credit facility | June Amendment | Base Rate | Minimum
Debt Instrument [Line Items]
Line of credit facility, basis spread on variable rate	0.75%
Senior credit facility | June Amendment | Base Rate | Maximum
Debt Instrument [Line Items]
Line of credit facility, basis spread on variable rate	1.75%
Junior Subordinated Debt | June Amendment
Debt Instrument [Line Items]
Outstanding junior debt threshold, reduction of maximum borrowing base	$ 1,500,000,000
Convertible Debt
Debt Instrument [Line Items]
Debt issuance costs							6,300,000
Debt conversion, original debt, amount							$ 255,300,000
Conversion ratio							0.3636
Convertible debt, threshold percentage of stock price trigger							40.00%
Initial conversion price threshold (usd per share) | $ / shares							$ 1.10
Convertible Debt | 8.125% Convertible Senior Notes due 2022
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		8.125%	8.125%				8.125%	8.125%
Embedded derivative, fair value							$ 21,874,000
Long term debt, discount							180,751,000
Aggregate Principle of Notes Converted		$ 269,400,000	$ 158,400,000
Debt conversion, original debt, amount							186,600,000
Debt conversion, original debt aggregate principal, net of discount and including holder's conversion feature							$ 54,400,000
Convertible Debt | 7.5% Convertible Senior Notes due 2023
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		7.50%	7.50%				7.50%	7.50%
Embedded derivative, fair value							$ 7,481,000
Long term debt, discount							59,549,000
Aggregate Principle of Notes Converted			$ 116,600,000
Debt conversion, original debt, amount							68,700,000
Debt conversion, original debt aggregate principal, net of discount and including holder's conversion feature							19,300,000
Secured Debt | 8.75% Senior Secured Notes Due 2020
Debt Instrument [Line Items]
Debt instrument, face amount		$ 78,000,000		$ 1,250,000,000		$ 1,250,000,000	$ 1,300,000,000
Long-term debt, fixed interest rate				8.75%		8.75%	8.75%
Proceeds from debt, net of issuance costs				$ 1,210,000,000
Fair value of Notes awarded		50,300,000
Embedded derivative, fair value		2,800,000					$ 2,941,000
Long term debt, discount		30,500,000					29,842,000
Debt issuance costs							39,200,000
Senior Notes
Debt Instrument [Line Items]
Debt issuance costs							$ 48,900,000
Debt instrument, repurchased face amount		100,000,000	250,000,000
Repurchase of unsecured notes		30,000,000	94,500,000
Debt conversion, original debt, amount		$ 300,000,000	$ 275,000,000
Senior Notes | 8.75% Senior Notes due 2020
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		8.75%	8.75%				8.75%	8.75%
Long term debt, discount							$ 3,269,000	$ 4,598,000
Mandatory prepayment feature, threshold amount of outstanding principal amount of senior notes							$ 100,000,000
Debt instrument, repurchased face amount		$ 2,200,000	$ 29,300,000
Debt conversion, original debt, amount		$ 6,600,000	$ 15,900,000
Senior Notes | 7.5% Senior Notes due 2021
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		7.50%	7.50%				7.50%	7.50%
Aggregate Principle of Notes Converted						$ 29,000,000
Debt instrument, repurchased face amount		$ 46,600,000	$ 111,600,000
Debt conversion, original debt, amount		$ 189,300,000	$ 40,700,000
Senior Notes | 8.125% Senior Notes due 2022
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		8.125%	8.125%				8.125%	8.125%
Aggregate Principle of Notes Converted						$ 21,000,000
Debt instrument, repurchased face amount			$ 26,100,000
Debt conversion, original debt, amount		$ 73,500,000	$ 101,800,000
Senior Notes | 7.5% Senior Notes due 2023
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		7.50%	7.50%				7.50%	7.50%
Long term debt, discount							$ 1,989,000	$ 3,452,000
Debt instrument, repurchased face amount		$ 51,200,000	$ 83,000,000
Debt conversion, original debt, amount		$ 30,600,000	$ 116,600,000
Senior Notes | 7.5% Senior Notes Due 2021 And 8.125% Senior Notes Due 2022
Debt Instrument [Line Items]
Common stock issued for debt (in shares) | shares						28
Aggregate Principle of Notes Converted						$ 50,000,000
Debt conversion, original debt, amount							$ 50,000,000
Senior Notes | 9.875% Senior Notes Due 2016
Debt Instrument [Line Items]
Long-term debt, fixed interest rate					9.875%
Debt tender offer, aggregate principal amount					$ 365,500,000
Debt instrument redemption price per principal amount (usd per principal amount) | $ / PrincipalAmount					1,061.34
Senior Notes | 8.0% Senior Notes Due 2018
Debt Instrument [Line Items]
Long-term debt, fixed interest rate					8.00%
Debt tender offer, aggregate principal amount					$ 750,000,000
Debt instrument redemption price per principal amount (usd per principal amount) | $ / PrincipalAmount					1,052.77

Derivatives - Offsetting Assets

Derivatives - Offsetting Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
ASSETS
Derivative assets, gross amounts	$ 85,524	$ 338,417
Derivative assets, gross amounts offset	(1,175)	0
Derivative assets, amounts net of offset	84,349	338,417
Derivative assets, financial collateral	0	0
Derivative assets, net amount	84,349	338,417
LIABILITIES
Derivative liabilities, gross amounts	1,748	0
Derivative liabilities, gross amounts offset	(1,175)	0
Derivative liabilities, amount net of offset	573	0
Derivative liabilities, financial collateral	(573)	0
Derivative liabilities, net amount	0	0
Current assets
ASSETS
Derivative assets, gross amounts	85,524	291,414
Derivative assets, gross amounts offset	(1,175)	0
Derivative assets, amounts net of offset	84,349	291,414
Derivative assets, financial collateral	0	0
Derivative assets, net amount	84,349	291,414
Noncurrent assets
ASSETS
Derivative assets, gross amounts	0	47,003
Derivative assets, gross amounts offset	0	0
Derivative assets, amounts net of offset	0	47,003
Derivative assets, financial collateral	0	0
Derivative assets, net amount	0	47,003
Current liabilities
LIABILITIES
Derivative liabilities, gross amounts	1,748	0
Derivative liabilities, gross amounts offset	(1,175)	0
Derivative liabilities, amount net of offset	573	0
Derivative liabilities, financial collateral	(573)	0
Derivative liabilities, net amount	0	0
Noncurrent liabilities
LIABILITIES
Derivative liabilities, gross amounts	0	0
Derivative liabilities, gross amounts offset	0	0
Derivative liabilities, amount net of offset	0	0
Derivative liabilities, financial collateral	0	0
Derivative liabilities, net amount	$ 0	$ 0

Derivatives - Open Commodity De

Derivatives - Open Commodity Derivative Contracts (Details) - January 2016 - December 2016 Mcf in Thousands	12 Months Ended
	Dec. 31, 2015$ / Mcf$ / bblMBblsMcf
Oil price swaps
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional (Oil in MBbl/Natural Gas in MMcf) | MBbls	1,464
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf)	88.36
Natural gas basis swaps
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional (Oil in MBbl/Natural Gas in MMcf) | Mcf	10,980
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / Mcf	(0.38)
Oil collars—three way
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional (Oil in MBbl/Natural Gas in MMcf) | MBbls	2,556
Oil collars—three way | Purchased Put
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, floor (USD/bbl)	90
Put | Oil collars—three way | Sold
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, floor (USD/bbl)	83.14
Call | Oil collars—three way | Sold
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, cap (USD/bbl)	100.85

Derivatives - Fair Value of Der

Derivatives - Fair Value of Derivative Contracts (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Derivative assets	$ 85,524	$ 338,417
Derivative liabilities	(1,748)	0
Total net derivative contracts	51,480	338,417
Current assets
Derivatives, Fair Value [Line Items]
Derivative assets	85,524	291,414
Noncurrent assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	47,003
Current liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	(1,748)	0
Oil price swaps | Current assets
Derivatives, Fair Value [Line Items]
Derivative assets	68,224	204,072
Oil price swaps | Noncurrent assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	36,288
Natural gas price swaps | Current assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	29,648
Natural gas basis swaps | Current assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	350
Natural gas basis swaps | Current liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	(1,748)	0
Oil collars—three way | Current assets
Derivatives, Fair Value [Line Items]
Derivative assets	17,300	56,289
Oil collars—three way | Noncurrent assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	10,715
Natural gas collars | Current assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	1,055
Long-term debt holder conversion feature | Long-term debt
Derivatives, Fair Value [Line Items]
Derivative liabilities	(29,355)	0
Mandatory prepayment feature - PGC Senior Secured Notes | Long-term debt
Derivatives, Fair Value [Line Items]
Derivative liabilities	$ (2,941)	$ 0

Derivatives - Narrative (Detail

Derivatives - Narrative (Details)	1 Months Ended			3 Months Ended								12 Months Ended
	Feb. 28, 2014USD ($)	Apr. 30, 2013USD ($)	Feb. 28, 2013USD ($)	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Sep. 30, 2014USD ($)	Jun. 30, 2014USD ($)	Mar. 31, 2014USD ($)	Dec. 31, 2015USD ($)institution	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Oct. 31, 2015	Aug. 31, 2015
Derivative Instruments and Hedging Activities Disclosures [Line Items]
(Gain) loss on derivative contracts				$ (14,000,000)	$ (42,200,000)	$ 33,000,000	$ (49,800,000)	$ (329,200,000)	$ (132,600,000)	$ 85,300,000	$ 42,500,000	$ (73,061,000)	$ (334,011,000)	$ 47,123,000
Number of counterparties to open derivative contracts | institution												8
Interest expense												$ 321,421,000	244,109,000	270,234,000
Commodity Derivatives
Derivative Instruments and Hedging Activities Disclosures [Line Items]
(Gain) loss on derivative contracts												(73,100,000)	(334,000,000)	47,100,000
Commodity Derivatives | Cash
Derivative Instruments and Hedging Activities Disclosures [Line Items]
(Gain) loss on derivative contracts												$ (327,700,000)	$ 32,300,000	(800,000)
Interest rate swaps
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Interest expense														10,000
Interest rate swaps | Cash
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Interest expense														$ 2,400,000
Derivative Contracts Early Settlements | Commodity Derivatives | Cash
Derivative Instruments and Hedging Activities Disclosures [Line Items]
(Gain) loss on derivative contracts	$ 69,600,000		$ 29,600,000
Senior Floating Rate Notes due 2014 | Fixed To Floating Interest Rate Swap Through April 1st 2013
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, maturity date		Apr. 1, 2013
Derivative liability, notional amount		$ 350,000,000
Derivative, fixed interest rate		6.69%
Senior Notes | 8.75% Senior Notes due 2020
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Long-term debt, fixed interest rate				8.75%				8.75%				8.75%	8.75%		8.75%	8.75%
Mandatory prepayment feature, threshold amount of outstanding principal amount of senior notes				$ 100,000,000								$ 100,000,000
Lenders Of Senior Credit Facility [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of counterparties to open derivative contracts | institution												3

Asset Retirement Obligations -

Asset Retirement Obligations - Reconciliation of Beginning and Ending Aggregate Carrying Amounts of Asset Retirement Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligation, Roll Forward Analysis
Beginning balance	$ 54,402	$ 424,117	$ 498,410
Liability incurred upon acquiring and drilling wells	1,662	4,968	5,078
Revisions in estimated cash flows	44,060	(5,848)	(3,077)
Liability settled or disposed in current period	(1,023)	(377,927)	(113,071)
Accretion	4,477	9,092	36,777
Ending balance	103,578	54,402	424,117
Less: current portion	8,399	0	87,063
Asset retirement obligations, net of current	$ 95,179	$ 54,402	$ 337,054

Asset Retirement Obligations 97

Asset Retirement Obligations - Reconciliation of Beginning and Ending Aggregate Carrying Amounts of Asset Retirement Obligations (Additional Information) (Details) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Feb. 28, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Reconciliation Of Changes In Asset Retirement Obligations [Line Items]
Asset retirement obligation, liabilities settled		$ 1,023	$ 377,927	$ 113,071
Gulf of Mexico Properties
Reconciliation Of Changes In Asset Retirement Obligations [Line Items]
Asset retirement obligation, liabilities settled	$ 366,000

Commitments and Contingencies -

Commitments and Contingencies - Future Minimum Lease Payments under Noncancelable Operating Leases (Details) $ in Thousands	Dec. 31, 2015USD ($)
Years ending December 31
2,016	$ 584
2,017	555
2,018	485
2,019	72
2,020	0
Thereafter	0
Total future obligation	$ 1,696

Commitments and Contingencies99

Commitments and Contingencies - Oil and Natural Gas Transportation and Throughput Agreements (Details) - Transportation and Throughput Agreements $ in Thousands	Dec. 31, 2015USD ($)
Years ending December 31
2,016	$ 14,082
2,017	13,869
2,018	14,163
2,019	9,282
2,020	1,584
Thereafter	11,088
Total future obligation	$ 64,068

Commitments and Contingencie100

Commitments and Contingencies - Narrative (Details) Mcf in Millions	Oct. 07, 2015USD ($)	Apr. 05, 2011USD ($)	Dec. 31, 2015USD ($)$ / McfMcf	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Sep. 26, 2014director	Jul. 15, 2013plaintiff	Mar. 31, 2013claim	Mar. 06, 2013claim
Commitments and Contingencies Disclosure [Line Items]
Total rental expense under operating leases			$ 1,000,000	$ 1,700,000	$ 3,600,000
Number of independent company directors that formed a Special Litigation Committee | director						2
Number of claims consolidated by the court | claim									2
Treating Agreement
Commitments and Contingencies Disclosure [Line Items]
Contract agreement, term			30 years
Minimum delivery required (in Bcf) | Mcf			3,200
Initial shortfall price, per Mcf (in dollars per mcf) | $ / Mcf			0.25
Cumulative deliveries (in Bcf) | Mcf			73.1
Cumulative shortfall (in Bcf) | Mcf			439.6
Cumulative shortfall accrued			$ 109,900,000
Wesley West Minerals, Ltd and Longfellow Ranch Partners, LP
Commitments and Contingencies Disclosure [Line Items]
Loss contingency, damages sought, value		$ 45,500,000
General Land Office of the State of Texas
Commitments and Contingencies Disclosure [Line Items]
Loss contingency, damages sought, value		$ 13,000,000
Shareholder Derivative Actions
Commitments and Contingencies Disclosure [Line Items]
Number of putative shareholder derivative actions filed | claim								7
Rig Commitments
Commitments and Contingencies Disclosure [Line Items]
Minimum future commitments, 2016			2,500,000
Minimum future commitments, 2017			0
Federal Shareholder Derivative Litigation And Others | Pending Litigation
Commitments and Contingencies Disclosure [Line Items]
Proposed escrow fund amount to be established by insurers of individual defendants to litigation settlement	$ 38,000,000
James Hart And Other Named Plaintiffs
Commitments and Contingencies Disclosure [Line Items]
Number of additional plaintiffs | plaintiff							15
Reserve established for lawsuit			$ 5,100,000

Equity - Preferred Stock (Detai

Equity - Preferred Stock (Details) - shares	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
Class of Stock [Line Items]
Shares authorized (in shares)	50,000,000	50,000,000	50,000,000
8.5% Convertible perpetual preferred stock
Class of Stock [Line Items]
Shares outstanding at end of period (in shares)	2,650,000		2,650,000
7.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Shares outstanding at end of period (in shares)	2,770,000		3,000,000

Equity - Preferred Stock Additi

Equity - Preferred Stock Additional Information (Details) - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Class of Stock [Line Items]
Preferred stock, par value (in dollars per share)	$ 0.001	$ 0.001
7.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Preferred stock converted (in shares)	230,500
Common Stock
Class of Stock [Line Items]
Shares of common stock issued related to conversion of preferred stock (in shares)	2,968,000	18,423,000

Equity - Preferred Stock Terms

Equity - Preferred Stock Terms (Details) - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
8.5% Convertible perpetual preferred stock
Class of Stock [Line Items]
Preferred stock, dividend rate, percentage	8.50%	8.50%	8.50%
Liquidation preference per share (usd per share)	$ 100
Annual dividend per share (usd per share)	$ 8.50
Conversion rate per share to common stock (shares)	12.4805
7.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Preferred stock, dividend rate, percentage	7.00%	7.00%	7.00%
Liquidation preference per share (usd per share)	$ 100
Annual dividend per share (usd per share)	$ 7
Conversion rate per share to common stock (shares)	12.8791

Equity - Preferred Stock Divide

Equity - Preferred Stock Dividends (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Class of Stock [Line Items]
Dividends satisfied in shares of common stock	$ 16,188	$ 0	$ 0
8.5% Convertible perpetual preferred stock
Class of Stock [Line Items]
Dividends paid in cash	11,262	22,525	22,525
Dividends satisfied in shares of common stock	11,262	0	0
Accrued dividends at period end	8,447	8,447	8,447
7.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Dividends paid in cash	0	21,000	21,000
Dividends satisfied in shares of common stock	10,500	0	0
Accrued dividends at period end	13,125	2,625	2,625
Dividends in arrears	10,500	0	0
6.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Dividends paid in cash	0	12,000	12,000
Accrued dividends at period end	$ 0	$ 0	$ 5,500

Equity - Preferred Stock Div105

Equity - Preferred Stock Dividends, Additional Information (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	Aug. 17, 2015	May. 15, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
8.5% Convertible perpetual preferred stock
Class of Stock [Line Items]
Convertible perpetual preferred stock dividends (in shares)			18.6
Percentage multiplier used in calculation of value of shares issued			95.00%
Market value of common stock issued as dividends	$ 9.5
Common shares issued, value per preferred share (usd per share)	$ 3.58
Reduction to preferred stock dividends			$ 1.8
Preferred stock, dividend rate, percentage			8.50%	8.50%	8.50%
7.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Convertible perpetual preferred stock dividends (in shares)			5.7
Percentage multiplier used in calculation of value of shares issued			95.00%
Market value of common stock issued as dividends		$ 6.7
Common shares issued, value per preferred share (usd per share)		$ 2.23
Reduction to preferred stock dividends			$ 3.8
Preferred stock, dividend rate, percentage			7.00%	7.00%	7.00%
6.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Preferred stock, dividend rate, percentage				6.00%	6.00%

Equity - Common Stock (Details)

Equity - Common Stock (Details) - shares	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
Equity [Abstract]
Shares authorized (in shares)	1,800,000,000	1,800,000,000	800,000,000
Shares outstanding at end of period (in shares)	633,471,000		484,819,000
Shares held in treasury (in shares)	2,113,000		1,113,000

Equity - Treasury Stock Activit

Equity - Treasury Stock Activity (Details) - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Equity, Class of Treasury Stock [Line Items]
Value of shares withheld for taxes	$ 2,428	$ 6,373	$ 30,126
Value of shares retired	$ 0	$ 0	$ 0
Treasury Stock
Equity, Class of Treasury Stock [Line Items]
Number of shares withheld for taxes	1,872	1,034	5,679
Value of shares withheld for taxes	$ 2,428	$ 6,373	$ 30,126
Number of shares retired	1,872	1,034	5,679
Value of shares retired	$ 2,428	$ 6,373	$ 30,126

Equity - Narrative (Details)

Equity - Narrative (Details)	1 Months Ended			3 Months Ended	12 Months Ended
	Oct. 31, 2015USD ($)	Aug. 31, 2015USD ($)	Dec. 31, 2014USD ($)$ / sharesshares	Jun. 30, 2015$ / sharesshares	Dec. 31, 2015USD ($)shares	Dec. 31, 2014USD ($)$ / sharesshares	Dec. 31, 2013	Nov. 29, 2012right
Common Stock
Shares authorized (in shares)			800,000,000	1,800,000,000	1,800,000,000	800,000,000
Preferred stock, shares authorized (in shares)			50,000,000	50,000,000	50,000,000	50,000,000
Common stock issued for debt (in shares)					92,800,000
Shares repurchased then retired during period (in shares)						27,400,000
Shares repurchased then retired during period, value | $						$ 111,300,000
Broker fees and commission for shares repurchased, then retired | $						500,000
Additional paid-in capital—stockholder receivable | $			$ 2,500,000		$ 1,250,000	2,500,000
2014 Share Repurchase Program
Common Stock
Share repurchase program, maximum authorized amount | $			$ 200,000,000			$ 200,000,000
6.0% Convertible perpetual preferred stock
Preferred Stock
Preferred stock, dividend rate, percentage						6.00%	6.00%
Shares of common stock issued related to conversion of preferred stock (in shares)			18,400,000
Series A Junior Participating Preferred Stock | Stockholder Rights Plan
Common Stock
Number of Rights issued per common share | right								1
Common Stock and Preferred Stock
Common Stock
Shares authorized			850,000,000	1,850,000,000		850,000,000
Shares authorized, par value (usd per share) | $ / shares			$ 0.001	$ 0.001		$ 0.001
Common Stock
Preferred Stock
Shares of common stock issued related to conversion of preferred stock (in shares)					2,968,000	18,423,000
Common Stock
Common stock issued for debt (in shares)					120,881,000
Senior Notes
Common Stock
Debt conversion, original debt, amount | $	$ 300,000,000	$ 275,000,000
Senior Notes | Common Stock
Common Stock
Common stock issued for debt (in shares)					28,000,000
Convertible Debt
Common Stock
Debt conversion, original debt, amount | $					$ 255,300,000
Convertible Debt | Common Stock
Common Stock
Common stock issued for debt (in shares)					92,800,000
7.5% Senior Notes Due 2021 And 8.125% Senior Notes Due 2022 | Senior Notes
Common Stock
Common stock issued for debt (in shares)				28,000,000
Debt conversion, original debt, amount | $					$ 50,000,000

Share-Based Compensation - Summ

Share-Based Compensation - Summary of Unvested Restricted Stock Awards (Details) - Restricted Stock - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Number of Shares
Unvested shares/units outstanding at beginning of period	8,556	7,643	15,328
Granted (in shares)	2,928	6,367	7,462
Vested (in shares)	(5,186)	(3,432)	(13,395)
Forfeited / Canceled (in shares)	(672)	(2,022)	(1,752)
Unvested shares/units outstanding at end of period	5,626	8,556	7,643
Weighted- Average Grant Date Fair Value (usd per share)
Unvested restricted shares outstanding at beginning of period (in usd per share)	$ 6.39	$ 6.92	$ 8.07
Granted (in usd per share)	0.88	6.17	6.32
Vested (in usd per share)	4.95	7.04	7.85
Forfeited / Canceled (in usd per share)	6.38	6.60	7.33
Unvested restricted shares outstanding at end of period (in usd per share)	$ 4.85	$ 6.39	$ 6.92

Share-Based Compensation - S110

Share-Based Compensation - Summary of Unvested Restricted Stock Units (Details) - Restricted Stock Units shares in Thousands	12 Months Ended
	Dec. 31, 2015$ / sharesshares
Vesting Four Years from Grant Date
Number of Shares
Unvested shares/units outstanding at beginning of period	0
Granted (in shares)	11,095
Vested (in shares)	(2,200)
Forfeited / Canceled (in shares)	(767)
Unvested shares/units outstanding at end of period	8,128
Fair value per unit (usd per share)
Fair Value per Unit at end of period (usd per share) | $ / shares	$ 0.20
Vesting Two Years from Grant Date
Number of Shares
Unvested shares/units outstanding at beginning of period	0
Granted (in shares)	3,104
Vested (in shares)	(979)
Forfeited / Canceled (in shares)	(122)
Unvested shares/units outstanding at end of period	2,003
Minimum | Vesting Two Years from Grant Date
Fair value per unit (usd per share)
Fair Value per Unit at end of period (usd per share) | $ / shares	$ 0.04
Maximum | Vesting Two Years from Grant Date
Fair value per unit (usd per share)
Fair Value per Unit at end of period (usd per share) | $ / shares	$ 0.20

Share-Based Compensation - Perf

Share-Based Compensation - Performance Units/Performance Share Units - Fair Value Assumptions (Details) - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Performance Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Volatility factor	120.00%	55.60%
Weighted-average risk-free interest rate	0.70%	0.50%
Weighted-average fair value per unit (usd per unit)	$ 1.08	$ 13.85
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Volatility factor	95.30%
Weighted-average risk-free interest rate	1.10%
Weighted-average fair value per unit (usd per unit)	$ 0.10

Share-Based Compensation - P112

Share-Based Compensation - Performance Units/Performance Share Units Activity (Details) - shares shares in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Performance Units
Number of Shares
Outstanding at beginning of period (in shares)	66	31	0
Granted (in shares)	0	47	31
Vested (in shares)	(28)	0	0
Forfeited /canceled (in shares)	0	(12)	0
Outstanding at end of period (in shares)	38	66	31
Performance Units | Performance Period Ending December 2015
Number of Shares
Vested (in shares)	0	9	12
Unvested (in shares)	0	19	19
Performance Units | Performance Period Ending December 2016
Number of Shares
Vested (in shares)	26	13	0
Unvested (in shares)	12	25	0
Performance Share Units
Number of Shares
Outstanding at beginning of period (in shares)	0
Granted (in shares)	2,044
Forfeited /canceled (in shares)	(151)
Outstanding at end of period (in shares)	1,893	0
Performance Share Units | Performance Period Ending December 2017
Number of Shares
Vested (in shares)	695
Unvested (in shares)	1,198

Share-Based Compensation - Narr

Share-Based Compensation - Narrative (Details) - USD ($)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense		$ 21,700,000	$ 22,600,000	$ 90,200,000
Share-based compensation, capitalized		$ 5,900,000	$ 6,000,000	5,600,000
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)		4 years
Unrecognized compensation cost related to unvested awards		$ 18,000,000
Unrecognized compensation cost, period of recognition (in years)		1 year 10 months 24 days
Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)		4 years
Performance Unit and Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)	3 years
Performance Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation cost, period of recognition (in years)		1 year
Amount paid related to fully vested awards		$ 0
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation cost related to unvested awards		$ 100,000
Unrecognized compensation cost, period of recognition (in years)		2 years
Vesting Four Years from Grant Date | Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)		4 years
Unrecognized compensation cost related to unvested awards		$ 900,000
Unrecognized compensation cost, period of recognition (in years)		3 years 2 months 12 days
Vesting Two Years from Grant Date | Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)		2 years
Unrecognized compensation cost related to unvested awards		$ 200,000
Unrecognized compensation cost, period of recognition (in years)		1 year
Percentage vesting at the end of the first year		40.00%
Percentage vesting at the end of the second year		60.00%
Discount from common stock price using a credit spread, percentage		10.60%
Former Company Executives
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense				$ 48,500,000

Incentive and Deferred Compe114

Incentive and Deferred Compensation Plans (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jul. 31, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Final Payments Under Existing Cash Bonus Program
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Payments to employees	$ 10.9
Annual Incentive Plan
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Accrued bonuses		$ 21.6	$ 21.1
Minimum | Management Annual Incentive Plan
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Incentive plans, payout percentages of target values		0.00%
Maximum | Management Annual Incentive Plan
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Incentive plans, payout percentages of target values		200.00%
Deferred Compensation Plans
Defined Contribution Plan Disclosure [Line Items]
Retirement plan, employer matching contribution, percent of match		100.00%	100.00%	100.00%
Retirement plan, employer matching contribution, percent of employees' gross pay (up to)		10.00%	10.00%	15.00%
Retirement plan, cost recognized		$ 7.9	$ 8.7	$ 11
Deferred compensation plan, employer match percentage (up to)		10.00%	10.00%	15.00%
Deferred compensation plan, compensation expense		$ 2.9	$ 2	$ 2.7

Income Taxes - (Benefit) Provis

Income Taxes - (Benefit) Provision for Income Taxes (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current
Federal	$ 0	$ (1,160)	$ 3,842
State	123	(1,133)	1,842
Current, total	123	(2,293)	5,684
Deferred
Federal	0	0	0
State	0	0	0
Deferred, total	0	0	0
Total provision (benefit)	123	(2,293)	5,684
Noncontrolling Interest
Deferred
Total provision (benefit)	90	283	308
Parent
Deferred
Total provision (benefit)	$ 33	$ (2,576)	$ 5,376

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Provision (Benefit) for Income Taxes at Statutory Federal Tax Rate to Company's Actual Income Tax Benefit (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Reconciliation Of Provision Of Income Taxes [Line Items]
Total provision (benefit)	$ 123	$ (2,293)	$ 5,684
Parent
Reconciliation Of Provision Of Income Taxes [Line Items]
Computed at federal statutory rate	(1,512,325)	122,362	(178,078)
State taxes, net of federal benefit	(19,988)	4,145	(886)
Non-deductible expenses	816	1,895	2,589
Non-deductible debt costs	10,228	0	0
Stock-based compensation	6,700	1,467	7,611
Net effects of consolidating the non-controlling interests’ tax provisions	218,196	(34,614)	(13,901)
Change in valuation allowance	1,296,405	(96,769)	188,599
Other	1	(1,062)	(558)
Total provision (benefit)	$ 33	$ (2,576)	$ 5,376

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Deferred tax liabilities
Investments	$ 138,310	$ 272,902
Property, plant and equipment	0	364,576
Derivative contracts	30,989	113,735
Long-term debt	10,017	0
Total deferred tax liabilities	179,316	751,213
Deferred tax assets
Property, plant and equipment	807,275	0
Allowance for doubtful accounts	18,702	19,086
Net operating loss carryforwards	1,190,799	1,265,458
Compensation and benefits	18,607	19,867
Alternative minimum tax credits and other carryforwards	44,302	43,840
Asset retirement obligations	38,314	21,946
CO2 under-delivery shortfall penalty	40,654	27,674
Other	4,305	2,934
Total deferred tax assets	2,162,958	1,400,805
Valuation allowance	(1,983,642)	(649,592)	$ (753,500)
Net deferred tax liability	$ 0	$ 0

Income Taxes - Unrecognized Tax

Income Taxes - Unrecognized Tax Benefits (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Reconciliation of Unrecognized Tax Benefits
Unrecognized tax benefit at January 1	$ 77	$ 1,382
Changes to unrecognized tax benefits related to a prior year, increase	4
Changes to unrecognized tax benefits related to a prior year, decrease		(17)
Decreases to unrecognized tax benefits for settlements with tax authorities	0	(1,288)
Unrecognized tax benefit at December 31	$ 81	$ 77

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2010
Income Tax Disclosure [Abstract]
Valuation allowance	$ 1,983,642	$ 649,592	$ 753,500
Operating Loss Carryforwards [Line Items]
Unrecognized excess tax benefits from stock based compensation	17,700
Unrecognized tax benefits	$ 81	$ 77	$ 1,382
Earliest Tax Year
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards expiration year	2,025
Latest Tax Year
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards expiration year	2,035
Alternative Minimum Tax Credit Carryforward
Tax Credit Carryforward [Line Items]
Alternative minimum tax credits, not subject to expiration	$ 9,300
Domestic Tax Authority
Operating Loss Carryforwards [Line Items]
Federal net operating loss carryovers	3,200,000
Operating loss carryforwards subject to IRC Section 382 limitation				$ 929,400
Net operating loss carryovers, subject to expiration	$ 552,600

Income Taxes - Periods Open to

Income Taxes - Periods Open to Tax Examination (Details)	12 Months Ended
	Dec. 31, 2015
Domestic Tax Authority | Earliest Tax Year
Income Tax Contingency [Line Items]
Open tax year	2,012
Net Operating Loss And Other Carryforwards | Earliest Tax Year
Income Tax Contingency [Line Items]
Open tax year	2,005
Net Operating Loss And Other Carryforwards | Latest Tax Year
Income Tax Contingency [Line Items]
Open tax year	2,011
Minimum
Income Tax Contingency [Line Items]
Number of tax years open for state tax audit (in years)	3 years
Maximum
Income Tax Contingency [Line Items]
Number of tax years open for state tax audit (in years)	5 years

(Loss) Earnings per Share - Cal

(Loss) Earnings per Share - Calculation of Weighted Average Common Shares Outstanding used in Computation of Diluted Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Earnings Per Share [Abstract]
Net (Loss) Income, Basic	$ (664,579)	$ (649,526)	$ (1,375,556)	$ (1,045,834)	$ 254,295	$ 145,957	$ (46,775)	$ (150,217)	$ (3,735,495)	$ 203,260	$ (609,414)
Weighted Average Shares, basic (in shares)									521,936	479,644	481,148
(Loss) Earnings Per Share, Basic earnings per share (in dollars per share)	$ (1.13)	$ (1.23)	$ (2.78)	$ (2.19)	$ 0.55	$ 0.30	$ (0.10)	$ (0.31)	$ (7.16)	$ 0.42	$ (1.27)
Effect of dilutive securities
Net (Loss) Income, Restricted stock (in dollars)									$ 0	$ 0	$ 0
Weighted Average Shares, Restricted stock (in shares)									0	2,181	0
Net (Loss) Income, Convertible preferred stock (in dollars)									$ 0	$ 6,500	$ 0
Weighted Average Shares, Convertible preferred stock (in shares)									0	17,918	0
Net (Loss) Income, Convertible senior unsecured notes (in dollars)									$ 0
Weighted Average Shares, Convertible senior unsecured note (in shares)									0
Net (Loss) Income, Diluted									$ (3,735,495)	$ 209,760	$ (609,414)
Weighted Average Shares, diluted (in shares)									521,936	499,743	481,148
(Loss) Earnings Per Share, Diluted earnings per share (in dollars per share)	$ (1.13)	$ (1.23)	$ (2.78)	$ (2.19)	$ 0.48	$ 0.27	$ (0.10)	$ (0.31)	$ (7.16)	$ 0.42	$ (1.27)

(Loss) Earnings per Share - 122

(Loss) Earnings per Share - Calculation of Weighted Average Common Shares Outstanding used in Computation of Diluted Earnings Per Share (Additional Information) (Details) - shares shares in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Convertible Preferred Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share	71.2	71.7	90.1
Convertible Debt Securities
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share	48.5
Restricted Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share			0.5
8.125% Convertible Senior Notes due 2022, including holder conversion feature liabilities of $21,874, and net of $180,751 discount
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Long-term debt, fixed interest rate	8.125%
7.5% Convertible Senior Notes due 2023, including holder conversion feature liabilities of $7,481, and net of $59,549 discount
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Long-term debt, fixed interest rate	7.50%
8.5% Convertible perpetual preferred stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Preferred stock, dividend rate, percentage	8.50%	8.50%	8.50%
6.0% Convertible perpetual preferred stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Preferred stock, dividend rate, percentage		6.00%	6.00%
7.0% Convertible perpetual preferred stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Preferred stock, dividend rate, percentage	7.00%	7.00%	7.00%

Related Party Transactions - Na

Related Party Transactions - Narrative (Details) - USD ($) $ in Thousands, shares in Millions	3 Months Ended	12 Months Ended
	Sep. 30, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Sales to related parties				$ 1,600
Employee termination benefits		$ 12,451	$ 8,874	122,505
Employee Severance
Related Party Transaction [Line Items]
Employee termination benefits		12,500		23,200
Former Chairman and CEO Severance
Related Party Transaction [Line Items]
Employee termination benefits	$ 57,900
Severance, compensation cost of accelerated shares	$ 36,800
Severance, number of accelerated shares	6.3
Severance liability		1,500
Annual Sponsorship Amount
Related Party Transaction [Line Items]
Sponsorship fees				$ 3,300
Annual Lease Obligation to Related Party
Related Party Transaction [Line Items]
Related party transaction amounts		500
Leasehold Improvements under Lease with Related Party
Related Party Transaction [Line Items]
Related party transaction amounts		$ 3,300
Gulf Properties | Employee Severance
Related Party Transaction [Line Items]
Employee termination benefits			$ 8,900

Subsequent Events - Royalty Tru

Subsequent Events - Royalty Trust Distributions (Details) - Subsequent Event - USD ($) $ in Thousands	Feb. 26, 2016	Jan. 28, 2016
Royalty Trusts
Subsequent Event [Line Items]
Total Distribution		$ 23,093
Amount to be Distributed to Third-Party Unitholders	$ 19,609
Mississippian Trust I
Subsequent Event [Line Items]
Total Distribution		8,708
Amount to be Distributed to Third-Party Unitholders	6,367
Permian Trust
Subsequent Event [Line Items]
Total Distribution		7,560
Amount to be Distributed to Third-Party Unitholders	7,560
Mississippian Trust II
Subsequent Event [Line Items]
Total Distribution		$ 6,825
Amount to be Distributed to Third-Party Unitholders	$ 5,682

Subsequent Events - Narrative (

Subsequent Events - Narrative (Details) $ in Thousands, shares in Millions

Mar. 16, 2016USD ($)

Mar. 15, 2016USD ($)

Jan. 21, 2016USD ($)

Feb. 29, 2016USD ($)

Jan. 31, 2016USD ($)

Oct. 31, 2015USD ($)

Aug. 31, 2015USD ($)

Mar. 20, 2016USD ($)shares

Dec. 31, 2015USD ($)MMBoeshares

Dec. 31, 2014USD ($)

Dec. 31, 2013USD ($)

Mar. 21, 2016USD ($)

Mar. 11, 2016USD ($)

Feb. 16, 2016

Jun. 09, 2015USD ($)

Subsequent Event [Line Items]

Employee termination benefits

$ 12,451

$ 8,874

$ 122,505

Senior credit facility, borrowed amount

$ 0

0

Debt instrument, subjective acceleration clause, period

30 days

Cash paid, transfer of ownership of substantially all of oil and natural gas properties and midstream assets in Pinon and release from all past, current and future claims and obligations under existing agreement

$ 24,889

$ 0

$ 0

Common stock issued for debt (in shares) | shares

92.8

Aggregate cash payments for accrued interest and early conversion of debt

$ 30,500

Treating Agreement

Subsequent Event [Line Items]

Contract agreement, term

30 years

Cumulative shortfall accrued

$ 109,900

Shortfall incurred in period

$ 34,900

Discontinued Operations, Disposed of by Means Other than Sale | WTO Properties

Subsequent Event [Line Items]

Production, oil and natural gas (in MMBoe) | MMBoe

1.9

Proved reserves, oil and natural gas (in MMBoe) | MMBoe

24.6

Revenue

$ 14,600

Operating expenses

41,100

Senior credit facility

Subsequent Event [Line Items]

Line of credit facility, current borrowing capacity

$ 900,000

Senior Notes

Subsequent Event [Line Items]

Debt conversion, original debt, amount

$ 300,000

$ 275,000

Convertible Debt

Subsequent Event [Line Items]

Debt conversion, original debt, amount

255,300

June Amendment | Senior credit facility

Subsequent Event [Line Items]

Line of credit facility, current borrowing capacity

$ 500,000

8.5% Convertible perpetual preferred stock

Subsequent Event [Line Items]

Preferred stock, dividend rate, percentage

8.50%

8.50%

8.50%

Subsequent Event

Subsequent Event [Line Items]

Employee termination benefits

$ 17,400

Senior credit facility, borrowed amount

$ 488,900

Common stock issued for debt (in shares) | shares

84.4

Aggregate cash payments for accrued interest and early conversion of debt

$ 33,500

Subsequent Event | Treating Agreement

Subsequent Event [Line Items]

Contract agreement, term

30 years

Subsequent Event | Discontinued Operations, Disposed of by Means Other than Sale | WTO Properties

Subsequent Event [Line Items]

Cash paid, transfer of ownership of substantially all of oil and natural gas properties and midstream assets in Pinon and release from all past, current and future claims and obligations under existing agreement

$ 11,000

Subsequent Event | Performance Incentive Plan | Minimum

Subsequent Event [Line Items]

Incentive plan, payout percentages of target values

0.00%

Subsequent Event | Performance Incentive Plan | Maximum

Subsequent Event [Line Items]

Incentive plan, payout percentages of target values

200.00%

Subsequent Event | Senior Notes

Subsequent Event [Line Items]

Interest payments

$ 22,000

Subsequent Event | June Amendment | Senior credit facility

Subsequent Event [Line Items]

Line of credit facility, current borrowing capacity

$ 340,000

Line of credit facility, target borrowing capacity

$ 500,000

Subsequent Event | 8.5% Convertible perpetual preferred stock

Subsequent Event [Line Items]

Preferred stock, dividend rate, percentage

8.50%

7.5% Senior Notes due 2023 | Senior Notes

Subsequent Event [Line Items]

Long-term debt, fixed interest rate

7.50%

7.50%

7.50%

7.50%

Debt conversion, original debt, amount

$ 30,600

$ 116,600

7.5% Senior Notes due 2023 | Subsequent Event | Senior Notes

Subsequent Event [Line Items]

Long-term debt, fixed interest rate

7.50%

7.5% Senior Notes due 2021 | Senior Notes

Subsequent Event [Line Items]

Long-term debt, fixed interest rate

7.50%

7.50%

7.50%

7.50%

Debt conversion, original debt, amount

$ 189,300

$ 40,700

7.5% Senior Notes due 2021 | Subsequent Event | Senior Notes

Subsequent Event [Line Items]

Interest payments

$ 28,400

8.125% Convertible Senior Notes due 2022

Subsequent Event [Line Items]

Long-term debt, fixed interest rate

8.125%

8.125% Convertible Senior Notes due 2022 | Convertible Debt

Subsequent Event [Line Items]

Long-term debt, fixed interest rate

8.125%

8.125%

8.125%

8.125%

Debt conversion, original debt, amount

$ 186,600

8.125% Convertible Senior Notes due 2022 | Subsequent Event | Convertible Debt

Subsequent Event [Line Items]

Debt conversion, original debt, amount

200,500

7.5% Convertible Senior Notes due 2023

Subsequent Event [Line Items]

Long-term debt, fixed interest rate

7.50%

7.5% Convertible Senior Notes due 2023 | Convertible Debt

Subsequent Event [Line Items]

Long-term debt, fixed interest rate

7.50%

7.50%

7.50%

7.50%

Debt conversion, original debt, amount

$ 68,700

7.5% Convertible Senior Notes due 2023 | Subsequent Event | Convertible Debt

Subsequent Event [Line Items]

Debt conversion, original debt, amount

$ 31,600

Business Segment Information -

Business Segment Information - Summarized Financial Information Concerning Segments (Details) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Sep. 30, 2014USD ($)	Jun. 30, 2014USD ($)	Mar. 31, 2014USD ($)	Dec. 31, 2015USD ($)business_unitsegment	Dec. 31, 2014USD ($)segment	Dec. 31, 2013USD ($)segment
Segment Reporting [Abstract]
Reportable segments | segment									3	3	3
Business units | business_unit									3
Segment Reporting Information [Line Items]
Revenues	$ 143,642	$ 180,152	$ 229,607	$ 215,308	$ 346,881	$ 394,107	$ 374,714	$ 443,056	$ 768,709	$ 1,558,758	$ 1,983,388
Income (loss) from operations	(959,406)	$ (1,059,733)	$ (1,535,083)	$ (1,088,456)	373,984	$ 256,491	$ 42,079	$ (82,330)	(4,642,678)	590,224	(169,001)
Interest income (expense), net									(321,421)	(244,109)	(270,234)
Gain (loss) on extinguishment of debt									641,131	0	(82,005)
Other income (expense), net									2,040	3,490	12,445
(Loss) income before income taxes									(4,320,928)	349,605	(508,795)
Capital expenditures									701,615	1,608,889	1,423,883
Depreciation, depletion, amortization and accretion									371,772	503,023	666,645
Total assets	2,991,155				7,259,225				2,991,155	7,259,225
Exploration and Production
Segment Reporting Information [Line Items]
Revenues									707,434	1,422,900	1,834,160
Income (loss) from operations									(4,461,907)	713,716	62,509
Interest income (expense), net									(42)	100	1,168
Gain (loss) on extinguishment of debt									0		0
Other income (expense), net									1,368	(423)	5,487
(Loss) income before income taxes									(4,460,581)	713,393	69,164
Capital expenditures									656,022	1,508,100	1,319,012
Depreciation, depletion, amortization and accretion									324,471	443,573	605,242
Total assets	1,959,975				6,273,802				1,959,975	6,273,802
Drilling and Oil Field Services
Segment Reporting Information [Line Items]
Revenues									22,124	76,088	66,641
Income (loss) from operations									(59,999)	(37,564)	(40,155)
Interest income (expense), net									0	0	0
Gain (loss) on extinguishment of debt									0		0
Other income (expense), net									13	(541)	0
(Loss) income before income taxes									(59,986)	(38,105)	(40,155)
Capital expenditures									4,632	18,385	7,125
Depreciation, depletion, amortization and accretion									17,438	29,105	33,291
Total assets	27,621				115,083				27,621	115,083
Midstream Services
Segment Reporting Information [Line Items]
Revenues									33,809	55,394	79,460
Income (loss) from operations									(15,218)	(9,094)	(21,567)
Interest income (expense), net									0	0	(209)
Gain (loss) on extinguishment of debt									0		0
Other income (expense), net									253	9	(3,222)
(Loss) income before income taxes									(14,965)	(9,085)	(24,998)
Capital expenditures									21,556	44,606	55,706
Depreciation, depletion, amortization and accretion									11,742	10,085	7,972
Total assets	254,212				219,691				254,212	219,691
All Other
Segment Reporting Information [Line Items]
Revenues									5,342	4,376	3,127
Income (loss) from operations									(105,554)	(76,834)	(169,788)
Interest income (expense), net									(321,379)	(244,209)	(271,193)
Gain (loss) on extinguishment of debt									641,131		(82,005)
Other income (expense), net									406	4,445	10,180
(Loss) income before income taxes									214,604	(316,598)	(512,806)
Capital expenditures									19,405	37,798	42,040
Depreciation, depletion, amortization and accretion									18,121	20,260	20,140
Total assets	$ 749,347				$ 650,649				749,347	650,649
Operating Segments
Segment Reporting Information [Line Items]
Revenues									861,229	1,763,380	2,205,052
Operating Segments | Exploration and Production
Segment Reporting Information [Line Items]
Revenues									707,446	1,423,073	1,834,480
Operating Segments | Drilling and Oil Field Services
Segment Reporting Information [Line Items]
Revenues									67,358	192,944	187,456
Operating Segments | Midstream Services
Segment Reporting Information [Line Items]
Revenues									81,083	142,987	179,989
Operating Segments | All Other
Segment Reporting Information [Line Items]
Revenues									5,342	4,376	3,127
Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues									(92,520)	(204,622)	(221,664)
Intersegment Eliminations | Exploration and Production
Segment Reporting Information [Line Items]
Revenues									(12)	(173)	(320)
Intersegment Eliminations | Drilling and Oil Field Services
Segment Reporting Information [Line Items]
Revenues									(45,234)	(116,856)	(120,815)
Intersegment Eliminations | Midstream Services
Segment Reporting Information [Line Items]
Revenues									(47,274)	(87,593)	(100,529)
Intersegment Eliminations | All Other
Segment Reporting Information [Line Items]
Revenues									$ 0	$ 0	$ 0

Business Segment Information127

Business Segment Information - Summarized Financial Information Concerning Segments (Additional Information) (Details) - USD ($)	3 Months Ended					12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Full cost ceiling impairments					$ 164,800,000	$ 4,500,000,000	$ 164,800,000	$ 0
Asset impairment charges	$ 886,800,000	$ 1,100,000,000	$ 1,500,000,000	$ 1,100,000,000		4,534,689,000	192,768,000	26,280,000
Discontinued Operations, Disposed of by Sale | Permian Properties
Segment Reporting Information [Line Items]
Loss on sale of oil and gas property								398,900,000
Gas Treating Plants and other Midstream Assets
Segment Reporting Information [Line Items]
Asset impairment charges						7,100,000	600,000	12,200,000
Buildings
Segment Reporting Information [Line Items]
Asset impairment charges						15,400,000
Gas Gathering and Processing Equipment [Member]
Segment Reporting Information [Line Items]
Asset impairment charges						700,000
Corporate Asset
Segment Reporting Information [Line Items]
Asset impairment charges								2,900,000
CO2 Compression Facilities
Segment Reporting Information [Line Items]
Asset impairment charges								8,300,000
Exploration and Production
Segment Reporting Information [Line Items]
Full cost ceiling impairments						4,500,000,000	164,800,000
Drilling and Oil Field Services
Segment Reporting Information [Line Items]
Asset impairment charges						37,600,000	27,400,000	11,100,000
Midstream Services | Gas Treating Plants and other Midstream Assets
Segment Reporting Information [Line Items]
Asset impairment charges						$ 7,100,000	$ 600,000	$ 3,900,000

Business Segment Information128

Business Segment Information - Major Customers (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenue, Major Customer [Line Items]
Sales	$ 143,642	$ 180,152	$ 229,607	$ 215,308	$ 346,881	$ 394,107	$ 374,714	$ 443,056	$ 768,709	$ 1,558,758	$ 1,983,388
Plains Marketing, L.P.
Revenue, Major Customer [Line Items]
Sales									$ 318,018	$ 597,117	$ 491,258
Percentage of revenue									41.40%	38.30%	24.80%
Shell Trading (US) Company
Revenue, Major Customer [Line Items]
Sales											$ 347,422
Percentage of revenue											17.50%
Targa Pipeline Mid-Continent West OK LLC [Member]
Revenue, Major Customer [Line Items]
Sales									$ 231,649	$ 333,027	$ 211,838
Percentage of revenue									30.10%	21.40%	10.70%

Condensed Consolidating Fina129

Condensed Consolidating Financial Information - Condensed Consolidating Balance Sheets of SandRidge Energy, Inc. and Wholly Owned Subsidiary Guarantors and Non-Guarantors' (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current assets
Cash and cash equivalents	$ 435,588	$ 181,253	$ 814,663	$ 309,766
Accounts receivable, net	127,387	330,077
Intercompany accounts receivable	0	0
Derivative contracts	84,349	291,414
Prepaid expenses	6,833	7,981
Other current assets	19,931	21,193
Total current assets	674,088	831,918
Property, plant and equipment, net	2,234,702	6,215,057
Investment in subsidiaries	0	0
Derivative contracts	0	47,003
Other assets	82,365	165,247
Total assets	2,991,155	7,259,225
Current liabilities
Accounts payable and accrued expenses	428,417	683,392
Intercompany accounts payable	0	0
Derivative contracts	573	0
Deferred tax liability	0	95,843
Other current liabilities	0	5,216
Asset retirement obligations	8,399	0	87,063
Total current liabilities	437,389	784,451
Investment in subsidiaries	0	0
Long-term debt	3,631,506	3,195,436
Asset retirement obligations	95,179	54,402	337,054
Other long-term obligations	14,814	15,116
Total liabilities	4,178,888	4,049,405
Equity
SandRidge Energy, Inc. stockholders’ (deficit) equity	(1,697,917)	1,937,825
Noncontrolling interest	510,184	1,271,995
Total stockholders’ (deficit) equity	(1,187,733)	3,209,820	3,175,627	3,862,455
Total liabilities and stockholders’ (deficit) equity	2,991,155	7,259,225
Eliminations
Current assets
Cash and cash equivalents	0	0	0	0
Accounts receivable, net	0	(7)
Intercompany accounts receivable	(2,563,250)	(2,132,207)
Derivative contracts	0	(38,454)
Prepaid expenses	0	0
Other current assets	0	0
Total current assets	(2,563,250)	(2,170,668)
Property, plant and equipment, net	0	0
Investment in subsidiaries	(2,758,045)	(6,632,142)
Derivative contracts		0
Other assets	(5,902)	(5,902)
Total assets	(5,327,197)	(8,808,712)
Current liabilities
Accounts payable and accrued expenses	0	(7)
Intercompany accounts payable	(2,563,250)	(2,132,207)
Derivative contracts	0	(38,454)
Deferred tax liability		0
Other current liabilities		0
Asset retirement obligations	0
Total current liabilities	(2,563,250)	(2,170,668)
Investment in subsidiaries	(1,439,074)	(1,062,230)
Long-term debt	(5,902)	(5,902)
Asset retirement obligations	0	0
Other long-term obligations	0	0
Total liabilities	(4,008,226)	(3,238,800)
Equity
SandRidge Energy, Inc. stockholders’ (deficit) equity	(1,829,155)	(6,841,907)
Noncontrolling interest	510,184	1,271,995
Total stockholders’ (deficit) equity	(1,318,971)	(5,569,912)
Total liabilities and stockholders’ (deficit) equity	(5,327,197)	(8,808,712)
Parent
Current assets
Cash and cash equivalents	426,917	170,468	805,505	300,228
Accounts receivable, net	0	7
Intercompany accounts receivable	1,226,994	751,376
Derivative contracts	0	0
Prepaid expenses	0	0
Other current assets	0	0
Total current assets	1,653,911	921,851
Property, plant and equipment, net	0	0
Investment in subsidiaries	2,749,514	6,606,198
Derivative contracts		0
Other assets	72,259	152,286
Total assets	4,475,684	7,680,335
Current liabilities
Accounts payable and accrued expenses	160,122	151,825
Intercompany accounts payable	1,337,688	1,365,210
Derivative contracts	0	0
Deferred tax liability		95,843
Other current liabilities		0
Asset retirement obligations	0
Total current liabilities	1,497,810	1,612,878
Investment in subsidiaries	1,038,303	928,217
Long-term debt	3,637,408	3,201,338
Asset retirement obligations	0	0
Other long-term obligations	80	77
Total liabilities	6,173,601	5,742,510
Equity
SandRidge Energy, Inc. stockholders’ (deficit) equity	(1,697,917)	1,937,825
Noncontrolling interest	0	0
Total stockholders’ (deficit) equity	(1,697,917)	1,937,825
Total liabilities and stockholders’ (deficit) equity	4,475,684	7,680,335
Guarantors
Current assets
Cash and cash equivalents	847	1,398	1,013	922
Accounts receivable, net	122,606	299,764
Intercompany accounts receivable	1,305,573	1,339,152
Derivative contracts	84,349	284,825
Prepaid expenses	6,826	7,971
Other current assets	19,931	21,193
Total current assets	1,540,132	1,954,303
Property, plant and equipment, net	2,124,532	5,137,702
Investment in subsidiaries	8,531	25,944
Derivative contracts		47,003
Other assets	16,008	18,197
Total assets	3,689,203	7,183,149
Current liabilities
Accounts payable and accrued expenses	265,767	526,941
Intercompany accounts payable	1,192,569	731,103
Derivative contracts	573	38,454
Deferred tax liability		0
Other current liabilities		5,216
Asset retirement obligations	8,399
Total current liabilities	1,467,308	1,301,714
Investment in subsidiaries	400,771	134,013
Long-term debt	0	0
Asset retirement obligations	95,179	54,402
Other long-term obligations	14,734	15,039
Total liabilities	1,977,992	1,505,168
Equity
SandRidge Energy, Inc. stockholders’ (deficit) equity	1,711,211	5,677,981
Noncontrolling interest	0	0
Total stockholders’ (deficit) equity	1,711,211	5,677,981
Total liabilities and stockholders’ (deficit) equity	3,689,203	7,183,149
Non-Guarantors
Current assets
Cash and cash equivalents	7,824	9,387	$ 8,145	$ 8,616
Accounts receivable, net	4,781	30,313
Intercompany accounts receivable	30,683	41,679
Derivative contracts	0	45,043
Prepaid expenses	7	10
Other current assets	0	0
Total current assets	43,295	126,432
Property, plant and equipment, net	110,170	1,077,355
Investment in subsidiaries	0	0
Derivative contracts		0
Other assets	0	666
Total assets	153,465	1,204,453
Current liabilities
Accounts payable and accrued expenses	2,528	4,633
Intercompany accounts payable	32,993	35,894
Derivative contracts	0	0
Deferred tax liability		0
Other current liabilities		0
Asset retirement obligations	0
Total current liabilities	35,521	40,527
Investment in subsidiaries	0	0
Long-term debt	0	0
Asset retirement obligations	0	0
Other long-term obligations	0	0
Total liabilities	35,521	40,527
Equity
SandRidge Energy, Inc. stockholders’ (deficit) equity	117,944	1,163,926
Noncontrolling interest	0	0
Total stockholders’ (deficit) equity	117,944	1,163,926
Total liabilities and stockholders’ (deficit) equity	$ 153,465	$ 1,204,453

Condensed Consolidating Fina130

Condensed Consolidating Financial Information - Condensed Consolidating Statements of Operations of SandRidge Energy, Inc. and Wholly Owned Subsidiary Guarantors and Non-Guarantors' (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
Total revenues	$ 143,642	$ 180,152	$ 229,607	$ 215,308	$ 346,881	$ 394,107	$ 374,714	$ 443,056	$ 768,709	$ 1,558,758	$ 1,983,388
Expenses
Direct operating expenses									375,354	483,889	682,830
General and administrative									150,166	122,865	330,425
Depreciation, depletion, amortization and accretion									371,772	503,023	666,645
Impairment	886,800	1,100,000	1,500,000	1,100,000					4,534,689	192,768	26,280
(Gain) loss on derivative contracts	(14,000)	(42,200)	33,000	(49,800)	(329,200)	(132,600)	85,300	42,500	(73,061)	(334,011)	47,123
Loss on settlement of contract									50,976	0	0
Loss (gain) on sale of assets									1,491	10	399,086
Total expenses									5,411,387	968,534	2,152,389
(Loss) income from operations	(959,406)	(1,059,733)	(1,535,083)	(1,088,456)	373,984	256,491	42,079	(82,330)	(4,642,678)	590,224	(169,001)
Equity earnings from subsidiaries									0	0	0
Interest (expense) income, net									(321,421)	(244,109)	(270,234)
Gain (loss) on extinguishment of debt									641,131	0	(82,005)
Other income (expense), net									2,040	3,490	12,445
(Loss) income before income taxes									(4,320,928)	349,605	(508,795)
Income tax expense (benefit)									123	(2,293)	5,684
Net (loss) income	$ (783,961)	$ (796,485)	$ (1,588,731)	$ (1,151,874)	$ 314,057	$ 197,499	$ (17,252)	$ (142,406)	(4,321,051)	351,898	(514,479)
Less: net (loss) income attributable to noncontrolling interest									(623,506)	98,613	39,410
Net (loss) income attributable to SandRidge Energy, Inc.									(3,697,545)	253,285	(553,889)
Eliminations
Condensed Financial Statements, Captions [Line Items]
Total revenues									(8)	(140)	(393)
Expenses
Direct operating expenses									(8)	(140)	(393)
General and administrative									0	0	0
Depreciation, depletion, amortization and accretion									0	0	0
Impairment									0	0	0
(Gain) loss on derivative contracts									0	0	0
Loss on settlement of contract									0
Loss (gain) on sale of assets									0		0
Total expenses									(8)	(140)	(393)
(Loss) income from operations									0	0	0
Equity earnings from subsidiaries									4,280,929	(534,121)	192,043
Interest (expense) income, net									0	0	0
Gain (loss) on extinguishment of debt									0		0
Other income (expense), net									0	0	0
(Loss) income before income taxes									4,280,929	(534,121)	192,043
Income tax expense (benefit)									0	0	0
Net (loss) income									4,280,929	(534,121)	192,043
Less: net (loss) income attributable to noncontrolling interest									(623,506)	98,613	39,410
Net (loss) income attributable to SandRidge Energy, Inc.									4,904,435	(632,734)	152,633
Parent
Condensed Financial Statements, Captions [Line Items]
Total revenues									0	0	0
Expenses
Direct operating expenses									0	0	0
General and administrative									213	331	329
Depreciation, depletion, amortization and accretion									0	0	0
Impairment									0	0	0
(Gain) loss on derivative contracts									0	0	0
Loss on settlement of contract									0
Loss (gain) on sale of assets									0		0
Total expenses									213	331	329
(Loss) income from operations									(213)	(331)	(329)
Equity earnings from subsidiaries									(4,017,082)	495,154	(195,118)
Interest (expense) income, net									(321,378)	(244,209)	(271,193)
Gain (loss) on extinguishment of debt									641,131		(82,005)
Other income (expense), net									0	0	0
(Loss) income before income taxes									(3,697,542)	250,614	(548,645)
Income tax expense (benefit)									3	(2,671)	5,244
Net (loss) income									(3,697,545)	253,285	(553,889)
Less: net (loss) income attributable to noncontrolling interest									0	0	0
Net (loss) income attributable to SandRidge Energy, Inc.									(3,697,545)	253,285	(553,889)
Guarantors
Condensed Financial Statements, Captions [Line Items]
Total revenues									682,778	1,341,531	1,675,481
Expenses
Direct operating expenses									364,483	467,175	654,080
General and administrative									145,796	118,249	323,808
Depreciation, depletion, amortization and accretion									339,647	446,149	581,435
Impairment									3,599,810	150,125	15,038
(Gain) loss on derivative contracts									(65,049)	(292,733)	24,702
Loss on settlement of contract									50,976
Loss (gain) on sale of assets									2,217		291,743
Total expenses									4,437,880	888,965	1,890,806
(Loss) income from operations									(3,755,102)	452,566	(215,325)
Equity earnings from subsidiaries									(263,847)	38,967	3,075
Interest (expense) income, net									(43)	100	959
Gain (loss) on extinguishment of debt									0		0
Other income (expense), net									1,910	3,521	16,173
(Loss) income before income taxes									(4,017,082)	495,154	(195,118)
Income tax expense (benefit)									0	0	0
Net (loss) income									(4,017,082)	495,154	(195,118)
Less: net (loss) income attributable to noncontrolling interest									0	0	0
Net (loss) income attributable to SandRidge Energy, Inc.									(4,017,082)	495,154	(195,118)
Non-Guarantors
Condensed Financial Statements, Captions [Line Items]
Total revenues									85,939	217,367	308,300
Expenses
Direct operating expenses									10,879	16,854	29,143
General and administrative									4,157	4,285	6,288
Depreciation, depletion, amortization and accretion									32,125	56,874	85,210
Impairment									934,879	42,643	11,242
(Gain) loss on derivative contracts									(8,012)	(41,278)	22,421
Loss on settlement of contract									0
Loss (gain) on sale of assets									(726)		107,343
Total expenses									973,302	79,378	261,647
(Loss) income from operations									(887,363)	137,989	46,653
Equity earnings from subsidiaries									0	0	0
Interest (expense) income, net									0	0	0
Gain (loss) on extinguishment of debt									0		0
Other income (expense), net									130	(31)	(3,728)
(Loss) income before income taxes									(887,233)	137,958	42,925
Income tax expense (benefit)									120	378	440
Net (loss) income									(887,353)	137,580	42,485
Less: net (loss) income attributable to noncontrolling interest									0	0	0
Net (loss) income attributable to SandRidge Energy, Inc.									$ (887,353)	$ 137,580	$ 42,485

Condensed Consolidating Fina131

Condensed Consolidating Financial Information - Condensed Consolidating Statements of Cash Flows of SandRidge Energy, Inc. and Wholly Owned Subsidiary Guarantors and Non-Guarantors' (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	$ 373,537	$ 621,114	$ 868,630
Cash flows from investing activities
Capital expenditures for property, plant and equipment	(879,201)	(1,553,332)	(1,496,731)
Acquisition of assets	(216,943)	(18,384)	(17,028)
Proceeds from sale of assets	56,504	714,475	2,584,115
Other	56,504	(18,384)	(17,028)
Net cash (used in) provided by investing activities	(1,039,640)	(857,241)	1,070,356
Cash flows from financing activities
Proceeds from borrowings	2,065,000	0	0
Repayments of borrowings	(939,466)	0	(1,115,500)
Premium on debt redemption	0	0	(61,997)
Distributions to unitholders	(138,305)	(193,807)	(206,470)
Repurchase of common stock	0	(111,827)	0
Dividends paid—preferred	(11,262)	(55,525)	(55,525)
Intercompany borrowings (advances) , net	0	0	0
Other	(66,791)	(91,649)	5,403
Net cash provided by (used in) financing activities	920,438	(397,283)	(1,434,089)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	254,335	(633,410)	504,897
CASH AND CASH EQUIVALENTS, beginning of year	181,253	814,663	309,766
CASH AND CASH EQUIVALENTS, end of year	435,588	181,253	814,663
Eliminations
Condensed Financial Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	51,272	8,438	907
Cash flows from investing activities
Capital expenditures for property, plant and equipment	0	0	0
Acquisition of assets	0
Proceeds from sale of assets		0	0
Other	(18,543)	(47,780)	(109,831)
Net cash (used in) provided by investing activities	(18,543)	(47,780)	(109,831)
Cash flows from financing activities
Proceeds from borrowings	0
Repayments of borrowings	0		0
Premium on debt redemption			0
Distributions to unitholders	20,324	40,520	93,205
Repurchase of common stock		0
Dividends paid—preferred			0
Intercompany borrowings (advances) , net	0	0	0
Other	(53,053)	(1,178)	15,719
Net cash provided by (used in) financing activities	(32,729)	39,342	108,924
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	0	0	0
CASH AND CASH EQUIVALENTS, beginning of year	0	0	0
CASH AND CASH EQUIVALENTS, end of year	0	0	0
Parent
Condensed Financial Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	(326,674)	(240,932)	(239,026)
Cash flows from investing activities
Capital expenditures for property, plant and equipment	0	0	0
Acquisition of assets	0
Proceeds from sale of assets		0	0
Other	0	0	0
Net cash (used in) provided by investing activities	0	0	0
Cash flows from financing activities
Proceeds from borrowings	2,065,000
Repayments of borrowings	(939,466)		(1,115,500)
Premium on debt redemption			(61,997)
Distributions to unitholders	0	0	0
Repurchase of common stock		(111,827)
Dividends paid—preferred			(55,525)
Intercompany borrowings (advances) , net	(475,618)	(215,368)	2,009,146
Other	(66,793)	(66,910)	(31,821)
Net cash provided by (used in) financing activities	583,123	(394,105)	744,303
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	256,449	(635,037)	505,277
CASH AND CASH EQUIVALENTS, beginning of year	170,468	805,505	300,228
CASH AND CASH EQUIVALENTS, end of year	426,917	170,468	805,505
Guarantors
Condensed Financial Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	524,313	641,181	852,026
Cash flows from investing activities
Capital expenditures for property, plant and equipment	(879,201)	(1,553,332)	(1,496,731)
Acquisition of assets	(216,943)
Proceeds from sale of assets		711,728	2,566,742
Other	74,140	28,256	89,606
Net cash (used in) provided by investing activities	(1,022,004)	(813,348)	1,159,617
Cash flows from financing activities
Proceeds from borrowings	0
Repayments of borrowings	0		0
Premium on debt redemption			0
Distributions to unitholders	0	0	0
Repurchase of common stock		0
Dividends paid—preferred			0
Intercompany borrowings (advances) , net	497,140	215,373	(2,018,212)
Other	0	(42,821)	6,660
Net cash provided by (used in) financing activities	497,140	172,552	(2,011,552)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(551)	385	91
CASH AND CASH EQUIVALENTS, beginning of year	1,398	1,013	922
CASH AND CASH EQUIVALENTS, end of year	847	1,398	1,013
Non-Guarantors
Condensed Financial Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	124,626	212,427	254,723
Cash flows from investing activities
Capital expenditures for property, plant and equipment	0	0	0
Acquisition of assets	0
Proceeds from sale of assets		2,747	17,373
Other	907	1,140	3,197
Net cash (used in) provided by investing activities	907	3,887	20,570
Cash flows from financing activities
Proceeds from borrowings	0
Repayments of borrowings	0		0
Premium on debt redemption			0
Distributions to unitholders	(158,629)	(234,327)	(299,675)
Repurchase of common stock		0
Dividends paid—preferred			0
Intercompany borrowings (advances) , net	(21,522)	(5)	9,066
Other	53,055	19,260	14,845
Net cash provided by (used in) financing activities	(127,096)	(215,072)	(275,764)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(1,563)	1,242	(471)
CASH AND CASH EQUIVALENTS, beginning of year	9,387	8,145	8,616
CASH AND CASH EQUIVALENTS, end of year	$ 7,824	$ 9,387	$ 8,145

Condensed Consolidating Fina132

Condensed Consolidating Financial Information - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2014USD ($)
Parent
Condensed Financial Statements, Captions [Line Items]
Net cash provided by (used in) operating activities, adjustments	$ (382.7)
Increase (decrease) in intercompany accounts payable	49.5
Increase (decrease) in accounts payable	(49.5)
Intercompany borrowings, adjustments	(382.7)
Guarantors
Condensed Financial Statements, Captions [Line Items]
Net cash provided by (used in) operating activities, adjustments	382.7
Increase (decrease) in intercompany accounts payable	(49.5)
Increase (decrease) in accounts payable	49.5
Property, plant and equipment net, adjustments	150.4
Intercompany borrowings, adjustments	382.7
Other investing activities, adjustments	193.8
Other financing Activities, Adjustments	(193.8)
Non-Guarantors
Condensed Financial Statements, Captions [Line Items]
Property, plant and equipment net, adjustments	(150.4)
Eliminations
Condensed Financial Statements, Captions [Line Items]
Other investing activities, adjustments	(193.8)
Other financing Activities, Adjustments	$ 193.8

Supplemental Information on 133

Supplemental Information on Oil and Natural Gas Producing Activities - Capitalized Costs Related to Oil and Natural Gas Producing Activities (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Oil and natural gas properties
Proved	$ 12,529,681	$ 11,707,147	$ 10,972,816
Unproved	363,149	290,596	531,606
Total oil and natural gas properties	12,892,830	11,997,743	11,504,422
Less: accumulated depreciation, depletion and impairment	(11,149,888)	(6,359,149)	(5,762,969)
Net oil and natural gas properties capitalized costs	$ 1,742,942	$ 5,638,594	$ 5,741,453

Supplemental Information on 134

Supplemental Information on Oil and Natural Gas Producing Activities - Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Acquisitions of properties
Proved	$ 35,376	$ 73,370	$ 21,130
Unproved	210,065	123,649	100,242
Exploration	29,297	41,070	82,775
Development	571,562	1,288,395	1,131,269
Total cost incurred	$ 846,300	$ 1,526,484	$ 1,335,416

Supplemental Information on 135

Supplemental Information on Oil and Natural Gas Producing Activities - Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development (Additional Information) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Exploration	$ 29,297	$ 41,070	$ 82,775
Seismic Costs
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Exploration	$ 7,100	$ 10,800	$ 6,700

Supplemental Information on 136

Supplemental Information on Oil and Natural Gas Producing Activities - Results of Operations from Oil and Natural Gas Producing Activities (Unaudited) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Extractive Industries [Abstract]
Revenues	$ 707,434	$ 1,420,879	$ 1,820,278
Expenses
Production costs	324,141	377,819	548,719
Depreciation and depletion	319,913	434,295	567,732
Accretion of asset retirement obligations	4,477	9,092	36,777
Impairment	4,473,787	164,779	0
Total expenses	5,122,318	985,985	1,153,228
(Loss) income before income taxes	(4,414,884)	434,894	667,050
Income tax expense (benefit)	126	(2,852)	(7,471)
Results of operations for oil and natural gas producing activities (excluding corporate overhead and interest costs)	$ (4,415,010)	$ 437,746	$ 674,521

Supplemental Information on 137

Supplemental Information on Oil and Natural Gas Producing Activities - Results of Operations from Oil and Natural Gas Producing Activities (Unaudited) (Additional Information) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Extractive Industries [Abstract]
Impairment	$ 4,473,787	$ 164,779	$ 0
Decrease in income tax benefit to include impact of the ceiling test impairment		$ 1,100

Supplemental Information on 138

Supplemental Information on Oil and Natural Gas Producing Activities - Summary of Changes in Estimated Oil and Natural Gas Reserves (Unaudited) (Details) Mcf in Thousands	12 Months Ended
	Dec. 31, 2015MBblsMcf	Dec. 31, 2014MBblsMcf	Dec. 31, 2013MBblsMcf	Dec. 31, 2012MBblsMcf
Oil Reserves
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Proved developed and undeveloped reserves, beginning balance	126,031	142,641	262,045
Revisions of previous estimates	(70,708)	(18,687)	(13,969)
Acquisitions of new reserves	22,447	1,009	43
Extensions and discoveries	9,741	37,603	40,570
Sales of reserves in place		(25,659)	(131,769)
Production	(9,600)	(10,876)	(14,279)
Proved developed and undeveloped reserves, ending balance	77,911	126,031	142,641
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	48,639	79,022	83,893	136,605
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	29,272	47,009	58,748	125,440
Natural Gas Liquids
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Proved developed and undeveloped reserves, beginning balance	91,786	59,052	67,994
Revisions of previous estimates	(37,384)	11,103	3,717
Acquisitions of new reserves	2,460	441	13
Extensions and discoveries	9,257	27,500	18,686
Sales of reserves in place		(2,516)	(29,067)
Production	(5,044)	(3,794)	(2,291)
Proved developed and undeveloped reserves, ending balance	61,075	91,786	59,052
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	51,089	56,823	35,807	33,785
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	9,986	34,963	23,245	34,209
Natural Gas
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Proved developed and undeveloped reserves, beginning balance | Mcf	1,788,233	1,390,429	1,415,042
Revisions of previous estimates | Mcf	(759,106)	167,589	(53,432)
Acquisitions of new reserves | Mcf	15,952	12,527	363
Extensions and discoveries | Mcf	160,865	467,185	359,918
Sales of reserves in place | Mcf		(163,800)	(228,229)
Production | Mcf	(92,104)	(85,697)	(103,233)
Proved developed and undeveloped reserves, ending balance | Mcf	1,113,840	1,788,233	1,390,429
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas) | Mcf	964,617	1,203,447	951,609	896,701
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas) | Mcf	149,223	584,786	438,820	518,341

Supplemental Information on 139

Supplemental Information on Oil and Natural Gas Producing Activities - Summary of Changes in Estimated Oil and Natural Gas Reserves - Noncontrolling Interests (Unaudited) (Additional Information) (Details) Mcf in Thousands	Dec. 31, 2015MBblsMcf	Dec. 31, 2014MBblsMcf	Dec. 31, 2013MBblsMcf	Dec. 31, 2012MBblsMcf
Oil Reserves
Reserve Quantities [Line Items]
Proved reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	77,911	126,031	142,641	262,045
Natural Gas Liquids
Reserve Quantities [Line Items]
Proved reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	61,075	91,786	59,052	67,994
Natural Gas Reserves
Reserve Quantities [Line Items]
Proved reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas) | Mcf	1,113,840	1,788,233	1,390,429	1,415,042
Non-controlling Interest | Oil Reserves
Reserve Quantities [Line Items]
Proved reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	7,004	11,027	13,569
Non-controlling Interest | Natural Gas Liquids
Reserve Quantities [Line Items]
Proved reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	3,694	4,761	4,737
Non-controlling Interest | Natural Gas Reserves
Reserve Quantities [Line Items]
Proved reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas) | Mcf	50,508	70,833	69,693

Supplemental Information on 140

Supplemental Information on Oil and Natural Gas Producing Activities - Calculation of Weighted Average Per Unit Prices (Unaudited) (Details)	12 Months Ended
	Dec. 31, 2015$ / Mcf$ / bbl	Dec. 31, 2014$ / Mcf$ / bbl	Dec. 31, 2013$ / Mcf$ / bbl
Oil Reserves
Average Sales Price and Production Costs Per Unit of Production [Line Items]
Weighted Average Sales Price (USD per barrel for Oil and NGLs/USD per Mcf for Natural Gas)	45.29	91.65	95.67
Natural Gas Liquids
Average Sales Price and Production Costs Per Unit of Production [Line Items]
Weighted Average Sales Price (USD per barrel for Oil and NGLs/USD per Mcf for Natural Gas)	12.68	32.79	31.40
Natural Gas
Average Sales Price and Production Costs Per Unit of Production [Line Items]
Weighted Average Sales Price (USD per barrel for Oil and NGLs/USD per Mcf for Natural Gas) | $ / Mcf	1.87	3.61	3.65

Supplemental Information on 141

Supplemental Information on Oil and Natural Gas Producing Activities - Standardized Measure of Discounted Future Cash Flows (Unaudited) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Extractive Industries [Abstract]
Future cash inflows from production	$ 6,387,944	$ 21,022,320	$ 19,937,484
Future production costs	(2,731,542)	(6,499,366)	(6,843,713)
Future development costs	(838,945)	(1,810,201)	(2,546,680)
Future income tax expenses	(901)	(3,223,740)	(2,283,541)
Undiscounted future net cash flows	2,816,556	9,489,013	8,263,550
10% annual discount	(1,501,994)	(5,401,261)	(4,245,939)
Standardized measure of discounted future net cash flows	$ 1,314,562	$ 4,087,752	$ 4,017,611	$ 5,840,368

Supplemental Information on 142

Supplemental Information on Oil and Natural Gas Producing Activities - Standardized Measure of Discounted Future Net Cash Flows (Unaudited) (Additional Information) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Standardized measure of discounted future net cash flows	$ 1,314,562	$ 4,087,752	$ 4,017,611	$ 5,840,368
Non-controlling Interest
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Standardized measure of discounted future net cash flows	$ 224,600	$ 643,300	$ 781,600

Supplemental Information on 143

Supplemental Information on Oil and Natural Gas Producing Activities - Estimate of Changes in Standardized Measure of Discounted Future Net Cash Flows from Proved Reserves (Unaudited) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Present value, beginning balance	$ 4,087,752	$ 4,017,611	$ 5,840,368
Changes during the year
Revenues less production and other costs	(383,293)	(1,043,060)	(1,271,559)
Net changes in prices, production and other costs	(3,813,465)	331,694	271,566
Development costs incurred	217,596	364,262	474,275
Net changes in future development costs	273,437	(341,183)	(207,729)
Extensions and discoveries	230,055	1,785,963	1,406,102
Revisions of previous quantity estimates	(1,354,778)	(77,688)	(296,418)
Accretion of discount	512,483	477,458	711,385
Net change in income taxes	1,426,333	(256,371)	477,328
Purchases of reserves in-place	18,429	50,958	1,628
Sales of reserves in-place	0	(1,058,330)	(3,172,187)
Timing differences and other	100,013	(163,562)	(217,148)
Net change for the year	(2,773,190)	70,141	(1,822,757)
Present value, ending balance	$ 1,314,562	$ 4,087,752	$ 4,017,611

Supplemental Information on 144

Supplemental Information on Oil and Natural Gas Producing Activities - Estimate of Changes in Standardized Measure of Discounted Future Net Cash Flows from Proved Reserves (Unaudited) (Additional Information) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Present value	$ 1,314,562	$ 4,087,752	$ 4,017,611	$ 5,840,368
Non-controlling Interest
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Present value	$ 224,600	$ 643,300	$ 781,600

Supplemental Information on 145

Supplemental Information on Oil and Natural Gas Producing Activities - Narrative (Details) Mcf in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)MMBoeMBblsMcf	Dec. 31, 2014USD ($)MMBoeMBblsMcf	Dec. 31, 2013USD ($)MMBoeMBblsMcf	Dec. 31, 2012USD ($)
Reserve Quantities [Line Items]
Percentage of proved reserves estimated by the Company	9.90%
Expected period without drilling activity		5 years
Acquisitions of new reserves (MMBoe) | MMBoe		3.5
Standardized measure of discounted future net cash flows | $	$ 1,314,562	$ 4,087,752	$ 4,017,611	$ 5,840,368
Oil Reserves
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas)	9,741	37,603	40,570
Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)	70,708	18,687	13,969
Natural Gas Reserves
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf	160,865	467,185	359,918
Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf	759,106	(167,589)	53,432
Natural Gas Liquids
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas)	9,257	27,500	18,686
Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)	37,384	(11,103)	(3,717)
Gulf Properties
Reserve Quantities [Line Items]
Sale of reserves in place (MMBoe) | MMBoe		55.5
Permian Properties
Reserve Quantities [Line Items]
Proved reserves (in MMBoe) | MMBoe			198.9
Proved developed reserves as a percentage of total proved reserves			55.00%
Standardized measure of discounted future net cash flows | $			$ 2,500,000
Lower Commodity Price | Oil Reserves
Reserve Quantities [Line Items]
Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)	54,000
Lower Commodity Price | Natural Gas Reserves
Reserve Quantities [Line Items]
Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf	687,000
Lower Commodity Price | Natural Gas Liquids
Reserve Quantities [Line Items]
Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)	36,000
North Park Basin, Jackson County, Colorado [Member]
Reserve Quantities [Line Items]
Acquisitions of new reserves (MMBoe) | MMBoe	27.6
Mid-Continent and Permian Basin | Oil Reserves
Reserve Quantities [Line Items]
Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)		2,000
Mid-Continent
Reserve Quantities [Line Items]
Extensions and discoveries (in MMBoe) | MMBoe			119.2
Mid-Continent | Oil Reserves
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas)	9,700
Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)	16,000	8,000
Mid-Continent | Natural Gas Reserves
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf	160,900
Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf	74,000
Mid-Continent | Natural Gas Liquids
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas)	9,300
Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)	1,000
Permian Properties | Oil Reserves
Reserve Quantities [Line Items]
Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)		9,000

Quarterly Financial Results 146

Quarterly Financial Results (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]
Total revenues	$ 143,642	$ 180,152	$ 229,607	$ 215,308	$ 346,881	$ 394,107	$ 374,714	$ 443,056	$ 768,709	$ 1,558,758	$ 1,983,388
(Loss) income from operations	(959,406)	(1,059,733)	(1,535,083)	(1,088,456)	373,984	256,491	42,079	(82,330)	(4,642,678)	590,224	(169,001)
Net (loss) income	(783,961)	(796,485)	(1,588,731)	(1,151,874)	314,057	197,499	(17,252)	(142,406)	(4,321,051)	351,898	(514,479)
(Loss applicable) income available to SandRidge Energy, Inc. common stockholders	$ (664,579)	$ (649,526)	$ (1,375,556)	$ (1,045,834)	$ 254,295	$ 145,957	$ (46,775)	$ (150,217)	$ (3,735,495)	$ 203,260	$ (609,414)
(Loss applicable) income available per share to SandRidge Energy, Inc. common stockholders
Basic (in dollars per share)	$ (1.13)	$ (1.23)	$ (2.78)	$ (2.19)	$ 0.55	$ 0.30	$ (0.10)	$ (0.31)	$ (7.16)	$ 0.42	$ (1.27)
Diluted (in dollars per share)	$ (1.13)	$ (1.23)	$ (2.78)	$ (2.19)	$ 0.48	$ 0.27	$ (0.10)	$ (0.31)	$ (7.16)	$ 0.42	$ (1.27)

Quarterly Financial Results (Ad

Quarterly Financial Results (Additional Information) (Details) - USD ($)	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Quarterly Financial Information [Line Items]
Full cost ceiling impairments								$ 164,800,000	$ 4,500,000,000	$ 164,800,000	$ 0
Asset impairment charges	$ 886,800,000	$ 1,100,000,000	$ 1,500,000,000	$ 1,100,000,000					4,534,689,000	192,768,000	26,280,000
(Gain) loss on derivative contracts	$ (14,000,000)	$ (42,200,000)	$ 33,000,000	$ (49,800,000)	$ (329,200,000)	$ (132,600,000)	$ 85,300,000	$ 42,500,000	(73,061,000)	(334,011,000)	47,123,000
Drilling Assets
Quarterly Financial Information [Line Items]
Asset impairment charges					$ 24,300,000		$ 3,100,000		37,600,000	3,100,000	11,100,000
Building and structures
Quarterly Financial Information [Line Items]
Asset impairment charges									15,400,000
Gas Treating Plants and other Midstream Assets
Quarterly Financial Information [Line Items]
Asset impairment charges									$ 7,100,000	$ 600,000	$ 12,200,000