SandRidge Energy (SD) 10-K 3 Mar 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Feb. 24, 2017	Jun. 30, 2016
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	Non-accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
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			$ 13.3
Entity Common Stock, Shares Outstanding		35,872,778

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Successor
Current assets
Cash and cash equivalents	$ 121,231
Restricted cash - collateral	50,000
Restricted cash - other	2,840
Accounts receivable, net	74,097
Derivative contracts	0
Prepaid expenses	5,375
Other current assets	3,633
Total current assets	257,176
Oil and natural gas properties, using full cost method of accounting
Proved (includes development and project costs excluded from amortization of $16.7 million and $34.6 million at December 31, 2016 and 2015, respectively)	840,201
Unproved	74,937
Less: accumulated depreciation, depletion and impairment	(353,030)
Net oil and natural gas properties capitalized costs	562,108
Other property, plant and equipment, net	255,824
Other assets	6,284
Total assets	1,081,392
Current liabilities
Accounts payable and accrued expenses	116,517
Derivative contracts	27,538
Asset retirement obligations	66,154
Other current liabilities	3,497
Total current liabilities	213,706
Long-term debt	305,308
Derivative contracts	2,176
Asset retirement obligations	40,327
Other long-term obligations	6,958
Total liabilities	568,475
Commitments and contingencies (Note 14)
SandRidge Energy, Inc. stockholders’ equity (deficit)
Common stock	20
Warrants	88,381
Additional paid-in capital	758,498
Additional paid-in capital - stockholder receivable	0
Treasury stock, at cost	0
Accumulated deficit	(333,982)
Total SandRidge Energy, Inc. stockholders’ equity (deficit)	512,917
Noncontrolling interest	0
Total stockholders’ equity (deficit)	512,917
Total liabilities and stockholders’ equity (deficit)	1,081,392
Successor | 8.5% Convertible perpetual preferred stock; 2,650 shares issued and outstanding at December 31, 2015; aggregate liquidation preference of $265,000
SandRidge Energy, Inc. stockholders’ equity (deficit)
Preferred stock	0
Successor | 7.0% Convertible perpetual preferred stock; 2,770 shares issued and outstanding at December 31, 2015, aggregate liquidation preference of $277,000
SandRidge Energy, Inc. stockholders’ equity (deficit)
Preferred stock	$ 0
Predecessor
Current assets
Cash and cash equivalents		$ 435,588
Restricted cash - collateral		0
Restricted cash - other		0
Accounts receivable, net		127,387
Derivative contracts		84,349
Prepaid expenses		6,833
Other current assets		19,931
Total current assets		674,088
Oil and natural gas properties, using full cost method of accounting
Proved (includes development and project costs excluded from amortization of $16.7 million and $34.6 million at December 31, 2016 and 2015, respectively)		12,529,681
Unproved		363,149
Less: accumulated depreciation, depletion and impairment		(11,149,888)
Net oil and natural gas properties capitalized costs		1,742,942
Other property, plant and equipment, net		491,760
Other assets		13,237
Total assets		2,922,027
Current liabilities
Accounts payable and accrued expenses		428,417
Derivative contracts		573
Asset retirement obligations		8,399
Other current liabilities		0
Total current liabilities		437,389
Long-term debt		3,562,378
Derivative contracts		0
Asset retirement obligations		95,179
Other long-term obligations		14,814
Total liabilities		4,109,760
Commitments and contingencies (Note 14)
SandRidge Energy, Inc. stockholders’ equity (deficit)
Common stock		630
Additional paid-in capital		5,301,136
Additional paid-in capital - stockholder receivable		(1,250)
Treasury stock, at cost		(5,742)
Accumulated deficit		(6,992,697)
Total SandRidge Energy, Inc. stockholders’ equity (deficit)		(1,697,917)
Noncontrolling interest		510,184
Total stockholders’ equity (deficit)		(1,187,733)
Total liabilities and stockholders’ equity (deficit)		2,922,027
Predecessor | 8.5% Convertible perpetual preferred stock; 2,650 shares issued and outstanding at December 31, 2015; aggregate liquidation preference of $265,000
SandRidge Energy, Inc. stockholders’ equity (deficit)
Preferred stock		3
Predecessor | 7.0% Convertible perpetual preferred stock; 2,770 shares issued and outstanding at December 31, 2015, aggregate liquidation preference of $277,000
SandRidge Energy, Inc. stockholders’ equity (deficit)
Preferred stock		$ 3

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
8.5% Convertible perpetual preferred stock; 2,650 shares issued and outstanding at December 31, 2015; aggregate liquidation preference of $265,000
Preferred stock, dividend rate, percentage		8.50%
7.0% Convertible perpetual preferred stock; 2,770 shares issued and outstanding at December 31, 2015, aggregate liquidation preference of $277,000
Preferred stock, dividend rate, percentage		7.00%
Successor
Development and project costs excluded from amortization	$ 16,700
Preferred stock, par value (in dollars per share)	$ 0
Preferred stock, shares authorized (in shares)	0
Common stock, par value (in dollars per share)	$ 0.001
Common stock, shares authorized (in shares)	250,000,000
Common stock, issued (in shares)	19,635,000
Common stock, outstanding (in shares)	19,635,000
Successor | 8.5% Convertible perpetual preferred stock; 2,650 shares issued and outstanding at December 31, 2015; aggregate liquidation preference of $265,000
Preferred stock, dividend rate, percentage	0.00%
Preferred stock, shares issued (in shares)	0
Preferred stock, shares outstanding (in shares)	0
Preferred stock, aggregate liquidation preference	$ 0
Successor | 7.0% Convertible perpetual preferred stock; 2,770 shares issued and outstanding at December 31, 2015, aggregate liquidation preference of $277,000
Preferred stock, dividend rate, percentage	0.00%
Preferred stock, shares issued (in shares)	0
Preferred stock, shares outstanding (in shares)	0
Preferred stock, aggregate liquidation preference	$ 0
Predecessor
Development and project costs excluded from amortization		$ 34,600
Preferred stock, par value (in dollars per share)		$ 0.001
Preferred stock, shares authorized (in shares)		50,000,000
Common stock, par value (in dollars per share)		$ 0.001
Common stock, shares authorized (in shares)		1,800,000,000
Common stock, issued (in shares)		635,584,000
Common stock, outstanding (in shares)		633,471,000
Predecessor | 8.5% Convertible perpetual preferred stock; 2,650 shares issued and outstanding at December 31, 2015; aggregate liquidation preference of $265,000
Preferred stock, dividend rate, percentage		8.50%
Preferred stock, shares issued (in shares)		2,650,000
Preferred stock, shares outstanding (in shares)		2,650,000
Preferred stock, aggregate liquidation preference		$ 265,000
Predecessor | 7.0% Convertible perpetual preferred stock; 2,770 shares issued and outstanding at December 31, 2015, aggregate liquidation preference of $277,000
Preferred stock, dividend rate, percentage		7.00%
Preferred stock, shares issued (in shares)		2,770,000
Preferred stock, shares outstanding (in shares)		2,770,000
Preferred stock, aggregate liquidation preference		$ 277,000

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Revenues
Oil, natural gas and NGL	$ 98,307
Other	149
Total revenues	98,456
Expenses
Production	24,997
Production taxes	2,643
Depreciation and depletion—oil and natural gas	33,971
Depreciation and amortization—other	3,922
Accretion of asset retirement obligations	2,090
Impairment	319,087
General and administrative	9,837
Employee termination benefits	12,334
Loss (gain) on derivative contracts	25,652
Loss on settlement of contract	0
Other operating expenses	268
Total expenses	434,801
(Loss) income from operations	(336,345)
Other (expense) income
Interest expense	(372)
Gain on extinguishment of debt	0
Gain on reorganization items, net	0
Other income, net	2,744
Total other income (expense)	2,372
(Loss) income before income taxes	(333,973)
Income tax expense (benefit)	9
Net (loss) income	(333,982)
Less: net (loss) income attributable to noncontrolling interest	0
Net (loss) income attributable to SandRidge Energy, Inc.	(333,982)
Preferred stock dividends	0
(Loss applicable) income available to SandRidge Energy, Inc. common stockholders	$ (333,982)
(Loss) earnings per share
Basic (in dollars per share)	$ (17.61)
Diluted (in dollars per share)	$ (17.61)
Weighted average number of common shares outstanding
Basic (in shares)	18,967
Diluted (in shares)	18,967
Predecessor
Revenues
Oil, natural gas and NGL		$ 279,971	$ 707,434	$ 1,420,879
Other		13,838	61,275	137,879
Total revenues		293,809	768,709	1,558,758
Expenses
Production		129,608	308,701	346,088
Production taxes		6,107	15,440	31,731
Depreciation and depletion—oil and natural gas		86,613	319,913	434,295
Depreciation and amortization—other		21,323	47,382	59,636
Accretion of asset retirement obligations		4,365	4,477	9,092
Impairment		718,194	4,534,689	192,768
General and administrative		116,091	137,715	113,991
Employee termination benefits		18,356	12,451	8,874
Loss (gain) on derivative contracts		4,823	(73,061)	(334,011)
Loss on settlement of contract		90,184	50,976	0
Other operating expenses		4,348	52,704	106,070
Total expenses		1,200,012	5,411,387	968,534
(Loss) income from operations		(906,203)	(4,642,678)	590,224
Other (expense) income
Interest expense		(126,099)	(321,421)	(244,109)
Gain on extinguishment of debt		41,179	641,131	0
Gain on reorganization items, net		2,430,599	0	0
Other income, net		1,332	2,040	3,490
Total other income (expense)		2,347,011	321,750	(240,619)
(Loss) income before income taxes		1,440,808	(4,320,928)	349,605
Income tax expense (benefit)		11	123	(2,293)
Net (loss) income		1,440,797	(4,321,051)	351,898
Less: net (loss) income attributable to noncontrolling interest		0	(623,506)	98,613
Net (loss) income attributable to SandRidge Energy, Inc.		1,440,797	(3,697,545)	253,285
Preferred stock dividends		16,321	37,950	50,025
(Loss applicable) income available to SandRidge Energy, Inc. common stockholders		$ 1,424,476	$ (3,735,495)	$ 203,260
(Loss) earnings per share
Basic (in dollars per share)		$ 2.01	$ (7.16)	$ 0.42
Diluted (in dollars per share)		$ 2.01	$ (7.16)	$ 0.42
Weighted average number of common shares outstanding
Basic (in shares)		708,928	521,936	479,644
Diluted (in shares)		708,928	521,936	499,743

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	Warrants	Additional Paid-In Capital	Treasury Stock	Accumulated Deficit	Non-controlling Interest
Beginning Balance (in shares) (Predecessor) at Dec. 31, 2013		7,650
Beginning Balance (in shares) (Predecessor) at Dec. 31, 2013			490,290
Beginning Balance (Predecessor) 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 | Predecessor	22,119				4,091			18,028
Distributions to noncontrolling interest owners | Predecessor	(193,807)							(193,807)
Purchase of treasury stock | Predecessor	(6,373)					(6,373)
Retirement of treasury stock | Predecessor	0				(6,373)	6,373
Stock distributions, net of purchases - retirement plans (in shares) | Predecessor			206
Stock distributions, net of purchases - retirement plans | Predecessor	9				(1,781)	1,790
Stock-based compensation | Predecessor	23,665				23,665
Stock-based compensation excess tax provision | Predecessor	14				14
Payment received on shareholder receivable | Predecessor	1,250				1,250
Issuance of restricted stock awards, net of cancellations (in shares) | Predecessor			3,311
Issuance of restricted stock awards, net of cancellations | Predecessor	0		$ 3		(3)
Common stock issued for debt | Predecessor	0
Acquisition of ownership interest | Predecessor	(2,730)				(2,074)			(656)
Repurchase of common stock (in shares) | Predecessor			(27,411)
Repurchase of common stock | Predecessor	(111,827)		$ (27)		(111,800)
Conversion of preferred stock to common stock (in shares) | Predecessor		(2,000)	18,423
Conversion of preferred stock to common stock | Predecessor	0	$ (2)	$ 18		(16)
Net (loss) income | Predecessor	351,898						253,285	98,613
Convertible perpetual preferred stock dividends | Predecessor	(50,025)						(50,025)
Ending Balance (in shares) (Predecessor) at Dec. 31, 2014		5,650
Ending Balance (in shares) (Predecessor) at Dec. 31, 2014			484,819
Ending Balance (Predecessor) 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 | Predecessor	(138,305)							(138,305)
Purchase of treasury stock | Predecessor	(2,428)					(2,428)
Retirement of treasury stock | Predecessor	0				(2,428)	2,428
Stock distributions, net of purchases - retirement plans (in shares) | Predecessor			(1,000)
Stock distributions, net of purchases - retirement plans | Predecessor	322				(916)	1,238
Stock-based compensation | Predecessor	21,123				21,123
Payment received on shareholder receivable | Predecessor	1,250				1,250
Issuance of restricted stock awards, net of cancellations (in shares) | Predecessor			1,514
Issuance of restricted stock awards, net of cancellations | Predecessor	$ 0		$ 5		(5)
Common stock issued for debt (in shares) | Predecessor	92,800		120,881
Common stock issued for debt | Predecessor	$ 63,299		$ 121		63,178
Conversion of preferred stock to common stock (in shares) | Predecessor		(230)	2,968
Conversion of preferred stock to common stock | Predecessor	0	$ 0	$ 3		(3)
Net (loss) income | Predecessor	(4,321,051)						(3,697,545)	(623,506)
Convertible perpetual preferred stock dividends (in shares) | Predecessor			24,289
Convertible perpetual preferred stock dividends | Predecessor	$ (21,763)		$ 24		16,163		(37,950)
Ending Balance (in shares) (Predecessor) at Dec. 31, 2015		5,420
Ending Balance (in shares) (Predecessor) at Dec. 31, 2015	633,471		633,471
Ending Balance (Predecessor) at Dec. 31, 2015	$ (1,187,733)	$ 6	$ 630		5,299,886	(5,742)	(6,992,697)	510,184
Increase (Decrease) in Stockholders' Equity
Cumulative effect of adoption of ASU 2015-02 | Predecessor	(253,124)						257,081	(510,205)
Purchase of treasury stock | Predecessor	(44)					(44)
Retirement of treasury stock | Predecessor	0				(44)	44
Stock distributions, net of purchases - retirement plans (in shares) | Predecessor			603
Stock distributions, net of purchases - retirement plans | Predecessor	(336)				(860)	524
Stock-based compensation | Predecessor	11,102				11,102
Issuance of restricted stock awards, net of cancellations (in shares) | Predecessor			(2,184)
Issuance of restricted stock awards, net of cancellations | Predecessor	$ 0		$ 2		(2)
Common stock issued for debt (in shares) | Predecessor	84,400		84,390
Common stock issued for debt | Predecessor	$ 4,409		$ 84		4,325
Conversion of preferred stock to common stock (in shares) | Predecessor		(173)	2,220
Conversion of preferred stock to common stock | Predecessor	0		$ 2		(2)
Net (loss) income | Predecessor	1,440,797						1,440,797
Convertible perpetual preferred stock dividends | Predecessor	$ (16,321)						(16,321)
Ending Balance (in shares) (Predecessor) at Oct. 01, 2016		0
Ending Balance (in shares) (Predecessor) at Oct. 01, 2016			0	0
Ending Balance (in shares) (Successor) at Oct. 01, 2016	19,371		18,932	6,442
Ending Balance (in shares) at Oct. 01, 2016			18,932	6,442
Ending Balance (Predecessor) at Oct. 01, 2016	$ 0	$ 0	$ 0	$ 0	0	0	0	0
Ending Balance (Successor) at Oct. 01, 2016	827,424		19	88,382	739,023	0	0
Ending Balance at Oct. 01, 2016	827,424		$ 19	88,382	739,023	0	0
Increase (Decrease) in Stockholders' Equity
Cancellation of Predecessor equity (in shares) | Predecessor		(5,247)	(718,500)
Cancellation of Predecessor equity | Predecessor	1,250	$ (6)	$ (718)		(5,314,405)	5,218	5,311,140	$ 21
Purchase of treasury stock | Successor	(110)					(110)
Retirement of treasury stock | Successor	0				(110)	110
Stock-based compensation | Successor	6,581				6,581
Common stock issued for debt (in shares) | Successor			693
Common stock issued for debt | Successor	13,001		$ 1		13,000
Issuance of stock awards, net of cancellations (in shares) | Successor			10
Issuance of stock awards, net of cancellations | Successor	0
Conversion of preferred stock to common stock | Successor	3			$ (1)	4
Net (loss) income | Successor	$ (333,982)						(333,982)
Ending Balance (in shares) (Successor) at Dec. 31, 2016	19,635		19,635	6,442
Ending Balance (Successor) at Dec. 31, 2016	$ 512,917		$ 20	$ 88,381	$ 758,498	$ 0	$ (333,982)

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income	$ (333,982)
Adjustments to reconcile net (loss) income to net cash provided by (used in) operating activities
Provision for doubtful accounts	(13,166)
Depreciation, depletion and amortization	37,893
Accretion of asset retirement obligations	2,090
Impairment	319,087
Gain on reorganization items, net	0
Debt issuance costs amortization	0
Amortization of discount, net of premium, on debt	(81)
Gain on extinguishment of debt	0
Write off of debt issuance costs	0
(Gain) loss on debt derivatives	0
Cash paid for early conversion of convertible notes	0
Loss (gain) on derivative contracts	25,652
Cash received on settlement of derivative contracts	7,698
Loss on settlement of contract	0
Cash paid on settlement of contract	0
Stock-based compensation	6,250
Other	717
Changes in operating assets and liabilities increasing (decreasing) cash
Deconsolidation of noncontrolling interest	0
Receivables	12,872
Prepaid expenses	(1,079)
Other current assets	(260)
Other assets and liabilities, net	1,505
Accounts payable and accrued expenses	990
Asset retirement obligations	(591)
Net cash provided by (used in) operating activities	65,595
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures for property, plant and equipment	(51,676)
Acquisitions of assets	0
Proceeds from sale of assets	11,841
Net cash used in investing activities	(39,835)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from borrowings	0
Repayments of borrowings	(414,954)
Debt issuance costs	0
Proceeds from building mortgage	0
Payment of mortgage proceeds and cash recovery to debt holders	0
Proceeds from the sale of royalty trust units	0
Noncontrolling interest distributions	0
Purchase of treasury stock	(110)
Repurchase of common stock	0
Dividends paid—preferred	0
Cash paid on settlement of financing derivative contracts	0
Other	3
Net cash (used in) provided by financing activities	(415,061)
NET (DECREASE) INCREASE IN CASH, CASH EQUIVALENTS and RESTRICTED CASH	(389,301)
CASH, CASH EQUIVALENTS and RESTRICTED CASH, beginning of year	563,372
CASH, CASH EQUIVALENTS and RESTRICTED CASH, end of year	174,071	$ 563,372
Predecessor
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income		1,440,797	$ (4,321,051)	$ 351,898
Adjustments to reconcile net (loss) income to net cash provided by (used in) operating activities
Provision for doubtful accounts		16,704	0	0
Depreciation, depletion and amortization		107,936	367,295	493,931
Accretion of asset retirement obligations		4,365	4,477	9,092
Impairment		718,194	4,534,689	192,768
Gain on reorganization items, net		(2,442,436)	0	0
Debt issuance costs amortization		4,996	11,884	9,425
Amortization of discount, net of premium, on debt		2,734	3,130	529
Gain on extinguishment of debt		(41,179)	(641,131)	0
Write off of debt issuance costs		0	7,108	0
(Gain) loss on debt derivatives		(1,324)	10,377	0
Cash paid for early conversion of convertible notes		(33,452)	(32,741)	0
Loss (gain) on derivative contracts		4,823	(73,061)	(334,011)
Cash received on settlement of derivative contracts		72,608	327,702	11,796
Loss on settlement of contract		90,184	50,976	0
Cash paid on settlement of contract		(11,000)	(24,889)	0
Stock-based compensation		9,075	18,380	19,994
Other		(3,260)	2,842	417
Changes in operating assets and liabilities increasing (decreasing) cash
Deconsolidation of noncontrolling interest		(9,654)	0	0
Receivables		36,116	201,907	(63,492)
Prepaid expenses		(5,681)	1,148	9,549
Other current assets		(181)	12,710	3,164
Other assets and liabilities, net		(7,542)	2,239	(1,132)
Accounts payable and accrued expenses		(61,305)	(86,470)	(66,492)
Asset retirement obligations		(3,595)	(3,984)	(16,322)
Net cash provided by (used in) operating activities		(112,077)	373,537	621,114
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures for property, plant and equipment		(186,452)	(879,201)	(1,553,332)
Acquisitions of assets		(1,328)	(216,943)	(18,384)
Proceeds from sale of assets		20,090	56,504	714,475
Net cash used in investing activities		(167,690)	(1,039,640)	(857,241)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from borrowings		489,198	2,065,000	0
Repayments of borrowings		(74,243)	(939,466)	0
Debt issuance costs		(333)	(53,244)	(3,947)
Proceeds from building mortgage		26,847	0	0
Payment of mortgage proceeds and cash recovery to debt holders		(33,874)	0	0
Proceeds from the sale of royalty trust units		0	0	22,119
Noncontrolling interest distributions		0	(138,305)	(193,807)
Purchase of treasury stock		(44)	(3,535)	(8,702)
Repurchase of common stock		0	0	(111,827)
Dividends paid—preferred		0	(11,262)	(55,525)
Cash paid on settlement of financing derivative contracts		0	0	(44,128)
Other		0	1,250	(1,466)
Net cash (used in) provided by financing activities		407,551	920,438	(397,283)
NET (DECREASE) INCREASE IN CASH, CASH EQUIVALENTS and RESTRICTED CASH		127,784	254,335	(633,410)
CASH, CASH EQUIVALENTS and RESTRICTED CASH, beginning of year	$ 563,372	435,588	181,253	814,663
CASH, CASH EQUIVALENTS and RESTRICTED CASH, end of year		$ 563,372	$ 435,588	$ 181,253

Voluntary Reorganization under

Voluntary Reorganization under Chapter 11 Proceedings	12 Months Ended
	Dec. 31, 2016
Reorganizations [Abstract]
Voluntary Reorganization under Chapter 11 Proceedings	Voluntary Reorganization under Chapter 11 Proceedings On May 16, 2016, the Company and certain of its direct and indirect subsidiaries (collectively with the Company, the “Debtors”) filed voluntary petitions (the “Bankruptcy Petitions”) for reorganization under Chapter 11 of the United States Bankruptcy Code (the “Bankruptcy Code”) in the United States Bankruptcy Court for the Southern District of Texas (the “Bankruptcy Court”). The Bankruptcy Court confirmed the Debtors’ joint plan of reorganization on September 9, 2016, and the Debtors’ subsequently emerged from bankruptcy on October 4, 2016 (the “Emergence Date”). Although the Company is no longer a debtor-in-possession, the Company was a debtor-in-possession through October 4, 2016. As such, the Company’s bankruptcy proceedings and related matters have been summarized below. The Company was able to conduct normal business activities and pay associated obligations for the period following its bankruptcy filing and was authorized to pay and has paid certain pre-petition obligations, including employee wages and benefits, goods and services provided by certain vendors, transportation of the Company’s production, royalties and costs incurred on the Company’s behalf by other working interest owners. During the pendency of the Chapter 11 case, all transactions outside the ordinary course of business required the prior approval of the Bankruptcy Court. Automatic Stay. Subject to certain specific exceptions under the Bankruptcy Code, the Chapter 11 filings automatically stayed most judicial or administrative actions against the Company and efforts by creditors to collect on or otherwise exercise rights or remedies with respect to pre-petition claims. Absent an order from the Bankruptcy Court, substantially all of the Debtors’ pre-petition liabilities were subject to settlement under the Bankruptcy Code. Plan of Reorganization. In accordance with the plan of reorganization confirmed by the Bankruptcy Court (the “Plan”), the following significant transactions occurred upon the Company’s emergence from bankruptcy on October 4, 2016: • First Lien Credit Agreement. All outstanding obligations under the senior secured revolving credit facility (the “senior credit facility”) were canceled, and claims under the senior credit facility received their proportionate share of (a) $35.0 million in cash and (b) participation in the newly established $425.0 million reserve-based revolving credit facility (the “New First Lien Exit Facility”). Refer to Note 11 for additional information. • Cash Collateral Account. The Company deposited $50.0 million of cash in an account controlled by the administrative agent to the New First Lien Exit Facility (the “Cash Collateral Account”) from the Emergence Date until the first borrowing base redetermination in October 2018 (the “Protected Period”); provided that (a) (i) $12.5 million will be released to the Company upon delivery of an acceptable business plan to the administrative agent, (ii) $12.5 million will be released to the Company upon achievement for two consecutive quarters of certain milestones set forth in the business plan and (b) to the extent the foregoing amounts are not released to the Company, up to $25.0 million will be released to the Company upon meeting a minimum 2.00 :1.00 ratio of proved developed producing reserves to aggregate principal loan commitments under the New First Lien Exit Facility at any time after July 4, 2017. If no default or event of default under the New First Lien Exit Facility exists at the expiration or termination of the Protected Period, all remaining proceeds in the Cash Collateral Account will be released to the Company at that time. • Senior Secured Notes . All outstanding obligations under the 8.75% Senior Secured Notes due 2020 issued in June 2015 and the $78.0 million principal 8.75% Senior Secured Notes due 2020 issued to Piñon Gathering Company, LLC (“PGC) in October 2015, (the “PGC Senior Secured Notes”) (collectively, “Senior Secured Notes”) were canceled and exchanged for approximately 13.7 million of the 18.9 million shares of common stock in the Successor Company (the “New Common Stock”) issued at emergence. Additionally, claims under the Senior Secured Notes received approximately $281.8 million principal amount of newly issued, non-interest bearing 0.00% convertible senior subordinated notes due 2020, (the “New Convertible Notes”), which are mandatorily convertible into approximately 15.0 million shares of New Common Stock upon the first to occur of several triggering events, one of which is refinancing of the New First Lien Exit Facility. Refer to Note 11 and Note 15 for additional information. • General Unsecured Claims. The Company’s general unsecured claims, including the 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, the “Senior Unsecured Notes”) and the 8.125% Convertible Senior Notes due 2022 and 7.5% Convertible Senior Notes due 2023 (collectively, the “Convertible Senior Unsecured Notes” and together with the Senior Unsecured Notes, the “Unsecured Notes”), became entitled to receive their proportionate share of (a) approximately $36.7 million in cash, (b) approximately 5.7 million shares of New Common Stock, 5.2 million of which was issued immediately upon emergence, and (c) 4.9 million Series A Warrants, 4.5 million issued immediately upon emergence, and 2.1 million Series B Warrants, 1.9 million issued immediately upon emergence, with initial exercise prices of $41.34 and $42.03 per share, respectively, which expire on October 4, 2022, (the “Warrants”). Refer to Note 11 and Note 15 for additional information. • New Building Note . A note with a principal amount of $35.0 million , which is secured by first priority mortgages on the Company’s headquarters facility and certain other non-oil and gas real property located in downtown Oklahoma City, Oklahoma (the “New Building Note”) was issued and purchased on the emergence date for $26.8 million in cash, net of certain fees and expenses, by certain holders of the Unsecured Senior Notes. Refer to Note 11 for additional information. • Preferred and Common Stock. The Company’s existing 7.0% and 8.5% convertible perpetual preferred stock and common stock were canceled and released under the Plan without receiving any recovery on account thereof. Refer to Note 15 for additional information. Additionally, pursuant to the Plan confirmed by the Bankruptcy Court, the Company’s post-emergence board of directors is comprised of five directors, including the Company’s Chief Executive Officer, James Bennett, and four non-employee directors, Michael L. Bennett, John V. Genova, William “Bill” M. Griffin, Jr. and David J. Kornder. Fresh Start Accounting Fresh Start Accounting. Upon emergence from bankruptcy, the Company applied fresh start accounting to its financial statements because (i) the holders of existing voting shares of the Company prior to its emergence received less than 50% of the voting shares of the Company outstanding following its emergence from bankruptcy and (ii) the reorganization value of the Company’s assets immediately prior to confirmation of the plan of reorganization was less than the post-petition liabilities and allowed claims. The Company elected to apply fresh start accounting effective October 1, 2016, to coincide with the timing of its normal fourth quarter reporting period, which resulted in SandRidge becoming a new entity for financial reporting purposes. The Company evaluated and concluded that events between October 1, 2016 and October 4, 2016 were immaterial and use of an accounting convenience date of October 1, 2016 was appropriate. As such, fresh start accounting is reflected in the accompanying consolidated balance sheet as of December 31, 2016 and related fresh start adjustments are included in the accompanying statement of operations for the period from January 1, 2016 through October 1, 2016 (the “Predecessor 2016 Period”). As a result of the application of fresh start accounting and the effects of the implementation of the Plan, the financial statements for the period after October 1, 2016 (the “Successor 2016 Period”) will not be comparable with the financial statements prior to that date. References to the “Successor” or the “Successor Company” relate to SandRidge subsequent to October 1, 2016. References to the “Predecessor” or “Predecessor Company” refer to SandRidge on and prior to October 1, 2016. Reorganization Value. Reorganization value represents the fair value of the Successor Company’s total assets and is intended to approximate the amount a willing buyer would pay for the assets immediately after restructuring. Under fresh start accounting, the Company allocated the reorganization value to its individual assets based on their estimated fair values. The Company’s reorganization value is derived from an estimate of enterprise value. Enterprise value represents the estimated fair value of an entity’s long term debt and other interest-bearing liabilities and shareholders’ equity. In support of the Plan, the Company estimated the enterprise value of the Successor Company to be in the range of $1.04 billion to $1.32 billion , which was subsequently approved by the Bankruptcy Court. This valuation analysis was prepared using reserve information, development schedules, other financial information and financial projections, third-party real estate reports, and applying standard valuation techniques, including net asset value analysis, precedent transactions analyses and public comparable company analyses. Based on the estimates and assumptions used in determining the enterprise value, the Company estimated the enterprise value to be approximately $1.09 billion . Valuation of Oil and Gas Properties. The Company’s principal assets are its oil and gas properties, which are accounted for under the Full Cost Accounting method as described in Note 3. With the assistance of valuation experts, the Company determined the fair value of its oil and gas properties based on the discounted cash flows expected to be generated from these assets. The computations were based on market conditions and reserves in place as of the bankruptcy emergence date. The fair value analysis performed by valuation experts was based on the Company’s estimates of proved reserves as developed internally by the Company’s reserves engineers. Discounted cash flow models were prepared using the estimated future revenues and development and operating costs for all developed wells and undeveloped locations comprising the proved reserves. Future revenues were based upon forward strip oil and natural gas prices as of the emergence date, adjusted for differentials realized by the Company. Development and operating costs from proved reserves estimates were adjusted for inflation. A risk adjustment factor was applied to the proved undeveloped reserve category. The discounted cash flow models also included estimates not typically included in proved reserves such as depreciation and income tax expenses. The risk adjusted after tax cash flows were discounted at 10% . This discount factor was derived from a weighted average cost of capital computation which utilized a blended expected cost of debt and expected returns on equity for similar industry participants. From this analysis the Company concluded the fair value of its proved reserves was $632.8 million as of the Emergence Date. The Company also reviewed its undeveloped leasehold acreage and concluded that the fair value of undeveloped leasehold acreage was $113.9 million based on analysis of comparable market transactions. These amounts are reflected in the Fresh Start Adjustments item number 14 below. The following table reconciles the enterprise value to the estimated fair value of the Successor Company's common stock as of the Emergence Date (in thousands, except per share amounts): Enterprise value $ 1,089,808 Plus: Cash and cash equivalents 563,372 Less: Fair value of New Building Note (36,610 ) Less: Asset retirement obligation (92,412 ) Less: Fair value of New First Lien Exit Facility (414,954 ) Less: Fair value of New Convertible Notes (445,660 ) Less: Fair value of warrants, including warrants held in reserve for settlement of general unsecured claims (95,794 ) Fair value of Successor common stock issued upon emergence $ 567,750 Shares issued upon emergence on October 4, 2016, including shares held in reserve for settlement of general unsecured claims 19,371 Per share value $ 29.31 The following table reconciles the enterprise value to the estimated reorganization value as of the Emergence Date (in thousands): Enterprise value $ 1,089,808 Plus: cash and cash equivalents 563,372 Plus: other working capital liabilities 131,766 Plus: other long-term liabilities 8,549 Reorganization value of Successor assets $ 1,793,495 Reorganization value and enterprise value were estimated using numerous projections and assumptions that are inherently subject to significant uncertainties and resolution of contingencies that are beyond our control. Accordingly, the estimates included in this report are not necessarily indicative of actual outcomes, and there can be no assurance that the estimates, projections or assumptions will be realized. Consolidated Balance Sheet. The adjustments included in the following consolidated balance sheet reflect the effects of the transactions contemplated by the Plan and carried out by the Company on the Emergence Date (reflected in the column “Reorganization Adjustments”) as well as fair value adjustments as a result of the adoption of fresh start accounting (reflected in the column “Fresh Start Adjustments”). The explanatory notes highlight methods used to determine fair values or other amounts of the assets and liabilities as well as significant assumptions. The following table reflects the reorganization and application of Accounting Standards Codification (“ASC”) 852 “Reorganizations” on the consolidated balance sheet as of October 1, 2016 (in thousands): Predecessor Company Reorganization Adjustments Fresh Start Adjustments Successor Company ASSETS Current assets Cash and cash equivalents $ 652,680 $ (142,148 ) (1) $ — $ 510,532 Restricted cash - collateral — 50,000 (2) — 50,000 Restricted cash - other — 2,840 (2) — 2,840 Accounts receivable, net 61,446 12,356 (3) — 73,802 Derivative contracts 10,192 — (669 ) (12) 9,523 Prepaid expenses 12,514 (8,218 ) (4) — 4,296 Other current assets 1,003 — 3,217 (13) 4,220 Total current assets 737,835 (85,170 ) 2,548 655,213 Oil and natural gas properties, using full cost method of accounting Proved 12,093,492 — (11,344,684 ) (14) 748,808 Unproved 322,580 — (205,578 ) (14) 117,002 Less: accumulated depreciation, depletion and impairment (11,637,538 ) — 11,637,538 (14) — 778,534 — 87,276 865,810 Other property, plant and equipment, net 357,528 (41 ) (93,782 ) (15) 263,705 Derivative contracts 70 — (70 ) (12) — Other assets 12,537 (3,770 ) (5) — 8,767 Total assets $ 1,886,504 $ (88,981 ) $ (4,028 ) $ 1,793,495 Predecessor Company Reorganization Adjustments Fresh Start Adjustments Successor Company LIABILITIES AND STOCKHOLDERS’ (DEFICIT) EQUITY Current liabilities Accounts payable and accrued expenses $ 140,448 $ (14,820 ) (6) $ — $ 125,628 Derivative contracts 2,982 — 1,666 (12) 4,648 Asset retirement obligations 8,573 — 57,105 (16) 65,678 Total current liabilities 152,003 (14,820 ) 58,771 195,954 Long-term debt — 731,735 (7) 1,610 (17) 733,345 Derivative contracts 935 — 304 (12) 1,239 Asset retirement obligations 62,896 — (36,161 ) (16) 26,735 Other long-term obligations 3 8,798 (8) (3 ) 8,798 Liabilities subject to compromise 4,346,188 (4,346,188 ) (9) — — Total liabilities 4,562,025 (3,620,475 ) 24,521 966,071 Equity SandRidge Energy, Inc. stockholders’ equity (deficit) Predecessor preferred stock 6 — (6 ) (18) — Predecessor common stock 718 — (718 ) (18) — Predecessor additional paid-in capital 5,315,655 — (5,315,655 ) (18) — Predecessor additional paid-in capital—stockholder receivable (1,250 ) 1,250 (10) — — Predecessor treasury stock, at cost (5,218 ) — 5,218 (18) — Successor common stock — 19 (11) — 19 Successor warrants — 88,382 (11) — 88,382 Successor additional paid-in capital — 739,023 (11) — 739,023 Accumulated deficit (7,985,411 ) 2,702,820 (9) 5,282,591 (19) — Total SandRidge Energy, Inc. stockholders’ (deficit) equity (2,675,500 ) 3,531,494 (28,570 ) 827,424 Noncontrolling interest (21 ) — 21 (20) — Total stockholders’ (deficit) equity (2,675,521 ) 3,531,494 (28,549 ) 827,424 Total liabilities and stockholders’ equity (deficit) $ 1,886,504 $ (88,981 ) $ (4,028 ) $ 1,793,495 Reorganization Adjustments 1. Reflects the net cash payments made upon emergence (in thousands): Sources: Proceeds from New Building Note $ 26,847 Total sources $ 26,847 Uses and transfers: Cash transferred to restricted accounts (collateral and general unsecured claims) $ 52,840 Payments and funding of escrow account related to professional fees 43,770 Payment on Senior Credit facility (principal and interest) 35,238 Repayment of Senior Secured Notes and Unsecured Notes 33,874 Payment of certain contract cures and other 3,273 Total uses and transfers 168,995 Net uses and transfers $ (142,148 ) 2. Funding of $50.0 million Cash Collateral account and the funding of $2.8 million to be held in reserve by the Company for distribution to satisfy allowed general unsecured claims as specified under the Plan. 3. Accrual for future reimbursement of the unused portion of the professional fees escrow account and other receivables. 4. Write-off of prepaid expenses primarily related to $7.5 million of prepaid premium for the Predecessor Company’s directors and officers insurance policy. 5. Application of a $3.8 million deposit held by a utility service toward the settlement of the utility service’s claims under the Plan. 6. Includes a $43.8 million decrease in accrued liabilities as a result of funding an escrow account established for the payment of professional fees, partially offset by the reinstatement of certain liabilities subject to compromise as accounts payable and accrued expenses. 7. Principal balances of $35.0 million of the New Building Note, $281.8 million of the New Convertible Notes, and the $415.0 million drawn on the New First Lien Exit Facility. 8. Reclassification of non-qualified deferred compensation plan and gas balancing liabilities from liabilities subject to compromise to other long term obligations, as these liabilities became obligations of the Successor. 9. Liabilities subject to compromise were settled as follows in accordance with the Plan (in thousands): Current maturities of long-term debt and accrued interest $ 4,179,483 Accounts payable and accrued expenses 157,422 Other long-term liabilities 9,283 Liabilities subject to compromise of the Predecessor 4,346,188 Cash payments at emergence (72,385 ) Cash proceeds from building mortgage 26,847 Write-off of prepaid accounts upon emergence (8,218 ) Accrual for future reimbursement from professional fees escrow account and other receivables 12,356 Total consideration given pursuant to the Plan: Fair value of equity issued (827,424 ) Principal value of long-term debt issued and reinstated at emergence (731,735 ) Reinstatement of liabilities subject to compromise as accounts payable and accrued expenses (37,789 ) Release of stockholder receivable (1,250 ) Application of deposit held by utility services (3,770 ) Gain on settlement of liabilities subject to compromise $ 2,702,820 10. Release of a receivable from the Predecessor’s former director and officer as outlined in the Plan. 11. The following table reconciles reorganization adjustments made to Successor common stock, warrants and additional paid in capital (in thousands): Par value of 18.9 million shares of New Common Stock issued to former holders of the Senior Secured Notes and Unsecured Notes (valued at $29.31 per share) $ 19 Fair value of warrants issued to holders of the Unsecured Notes(1) 88,382 Additional paid in capital - New Common Stock 575,144 Additional paid in capital - premium on New Convertible Notes(2) 163,879 Total Successor Company equity issued on Emergence Date $ 827,424 ____________________ (1) The fair value of the warrants was estimated using a Black-Scholes-Merton model with the following assumptions: implied stock price of the Successor Company; exercise price per share of $41.34 and $42.03 for Warrant classes A and B, respectively; expected volatility of 59.26% ; risk free interest rate, continuously compounded, of 1.36% ; and holding period of six years. (2) The fair value of the New Convertible Notes was estimated using a Monte Carlo simulation with the following assumptions; the implied Successor Company stock price; expected volatility of 56.06% ; risk free interest rate, continuously compounded, of 1.08% ; recovery rate of 15.00% ; hazard rate of 12.41% ; drop on default of 100.00% ; and termination period after four years. The premium is the difference between the fair value of the New Convertible Notes of $445.7 million and the principal value of the New Convertible Notes of $281.8 million . Fresh Start Adjustments 12. Adjustments and reclassifications of derivative contracts based on their Emergence Date fair values, which were determined using the fair value methodology for commodity derivative contracts discussed in Note 6. 13. Fair value adjustment to other current assets to record assets held for sale at their anticipated sales prices. 14. Fair value adjustments to oil and natural gas properties, including asset retirement obligation, associated inventory, unproved acreage and seismic. See above for detailed discussion of fair value methodology. 15. Adjustments to other property, plant and equipment to record the assets at their respective fair values on the Emergence Date. A combination of the cost approach and income approach were utilized to determine the fair values of the Company’s headquarters and other properties located in downtown Oklahoma City, Oklahoma, and the cost approach was utilized to determine the fair value of all other property, plant and equipment. 16. Fair value adjustments to the Company’s asset retirement obligations as a result of applying fresh start accounting. Upon implementation of fresh start accounting, the Company revalued these obligations based upon updates to wells’ productive lives and application of the Successor Company’s credit adjusted risk fee rate. 17. Fair value adjustment to record premium on the New Building Note. 18. Cancellation of Predecessor Company’s common stock, preferred stock, treasury stock and paid-in capital. 19. Adjustment to reset retained deficit to zero . 20. Elimination of the Predecessor non-controlling interest. Reorganization Items Reorganization items represent liabilities settled, net of amounts incurred subsequent to the Chapter 11 filing as a direct result of the Plan and are classified as gain on reorganization items, net in the accompanying consolidated statement of operations. The following table summarizes reorganization items for the Predecessor 2016 Period (in thousands): Unamortized long-term debt $ 3,546,847 Litigation claims (20,478 ) Rejections and cures of executory contracts (16,038 ) Ad valorem and franchise taxes (3,494 ) Legal and professional fees and expenses (44,920 ) Write off of director and officer insurance policy (7,533 ) Gain on accounts payable settlements 84,228 Loss on mortgage (8,153 ) Gain on preferred stock dividends 37,893 Fresh start valuation adjustments (28,549 ) Fair value of equity issued (827,424 ) Principal value of New Convertible Notes issued (281,780 ) Gain on reorganization items, net $ 2,430,599

Fresh Start Accounting

Fresh Start Accounting	12 Months Ended
	Dec. 31, 2016
Fresh-Start Adjustment [Line Items]
Fresh Start Accounting	Voluntary Reorganization under Chapter 11 Proceedings On May 16, 2016, the Company and certain of its direct and indirect subsidiaries (collectively with the Company, the “Debtors”) filed voluntary petitions (the “Bankruptcy Petitions”) for reorganization under Chapter 11 of the United States Bankruptcy Code (the “Bankruptcy Code”) in the United States Bankruptcy Court for the Southern District of Texas (the “Bankruptcy Court”). The Bankruptcy Court confirmed the Debtors’ joint plan of reorganization on September 9, 2016, and the Debtors’ subsequently emerged from bankruptcy on October 4, 2016 (the “Emergence Date”). Although the Company is no longer a debtor-in-possession, the Company was a debtor-in-possession through October 4, 2016. As such, the Company’s bankruptcy proceedings and related matters have been summarized below. The Company was able to conduct normal business activities and pay associated obligations for the period following its bankruptcy filing and was authorized to pay and has paid certain pre-petition obligations, including employee wages and benefits, goods and services provided by certain vendors, transportation of the Company’s production, royalties and costs incurred on the Company’s behalf by other working interest owners. During the pendency of the Chapter 11 case, all transactions outside the ordinary course of business required the prior approval of the Bankruptcy Court. Automatic Stay. Subject to certain specific exceptions under the Bankruptcy Code, the Chapter 11 filings automatically stayed most judicial or administrative actions against the Company and efforts by creditors to collect on or otherwise exercise rights or remedies with respect to pre-petition claims. Absent an order from the Bankruptcy Court, substantially all of the Debtors’ pre-petition liabilities were subject to settlement under the Bankruptcy Code. Plan of Reorganization. In accordance with the plan of reorganization confirmed by the Bankruptcy Court (the “Plan”), the following significant transactions occurred upon the Company’s emergence from bankruptcy on October 4, 2016: • First Lien Credit Agreement. All outstanding obligations under the senior secured revolving credit facility (the “senior credit facility”) were canceled, and claims under the senior credit facility received their proportionate share of (a) $35.0 million in cash and (b) participation in the newly established $425.0 million reserve-based revolving credit facility (the “New First Lien Exit Facility”). Refer to Note 11 for additional information. • Cash Collateral Account. The Company deposited $50.0 million of cash in an account controlled by the administrative agent to the New First Lien Exit Facility (the “Cash Collateral Account”) from the Emergence Date until the first borrowing base redetermination in October 2018 (the “Protected Period”); provided that (a) (i) $12.5 million will be released to the Company upon delivery of an acceptable business plan to the administrative agent, (ii) $12.5 million will be released to the Company upon achievement for two consecutive quarters of certain milestones set forth in the business plan and (b) to the extent the foregoing amounts are not released to the Company, up to $25.0 million will be released to the Company upon meeting a minimum 2.00 :1.00 ratio of proved developed producing reserves to aggregate principal loan commitments under the New First Lien Exit Facility at any time after July 4, 2017. If no default or event of default under the New First Lien Exit Facility exists at the expiration or termination of the Protected Period, all remaining proceeds in the Cash Collateral Account will be released to the Company at that time. • Senior Secured Notes . All outstanding obligations under the 8.75% Senior Secured Notes due 2020 issued in June 2015 and the $78.0 million principal 8.75% Senior Secured Notes due 2020 issued to Piñon Gathering Company, LLC (“PGC) in October 2015, (the “PGC Senior Secured Notes”) (collectively, “Senior Secured Notes”) were canceled and exchanged for approximately 13.7 million of the 18.9 million shares of common stock in the Successor Company (the “New Common Stock”) issued at emergence. Additionally, claims under the Senior Secured Notes received approximately $281.8 million principal amount of newly issued, non-interest bearing 0.00% convertible senior subordinated notes due 2020, (the “New Convertible Notes”), which are mandatorily convertible into approximately 15.0 million shares of New Common Stock upon the first to occur of several triggering events, one of which is refinancing of the New First Lien Exit Facility. Refer to Note 11 and Note 15 for additional information. • General Unsecured Claims. The Company’s general unsecured claims, including the 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, the “Senior Unsecured Notes”) and the 8.125% Convertible Senior Notes due 2022 and 7.5% Convertible Senior Notes due 2023 (collectively, the “Convertible Senior Unsecured Notes” and together with the Senior Unsecured Notes, the “Unsecured Notes”), became entitled to receive their proportionate share of (a) approximately $36.7 million in cash, (b) approximately 5.7 million shares of New Common Stock, 5.2 million of which was issued immediately upon emergence, and (c) 4.9 million Series A Warrants, 4.5 million issued immediately upon emergence, and 2.1 million Series B Warrants, 1.9 million issued immediately upon emergence, with initial exercise prices of $41.34 and $42.03 per share, respectively, which expire on October 4, 2022, (the “Warrants”). Refer to Note 11 and Note 15 for additional information. • New Building Note . A note with a principal amount of $35.0 million , which is secured by first priority mortgages on the Company’s headquarters facility and certain other non-oil and gas real property located in downtown Oklahoma City, Oklahoma (the “New Building Note”) was issued and purchased on the emergence date for $26.8 million in cash, net of certain fees and expenses, by certain holders of the Unsecured Senior Notes. Refer to Note 11 for additional information. • Preferred and Common Stock. The Company’s existing 7.0% and 8.5% convertible perpetual preferred stock and common stock were canceled and released under the Plan without receiving any recovery on account thereof. Refer to Note 15 for additional information. Additionally, pursuant to the Plan confirmed by the Bankruptcy Court, the Company’s post-emergence board of directors is comprised of five directors, including the Company’s Chief Executive Officer, James Bennett, and four non-employee directors, Michael L. Bennett, John V. Genova, William “Bill” M. Griffin, Jr. and David J. Kornder. Fresh Start Accounting Fresh Start Accounting. Upon emergence from bankruptcy, the Company applied fresh start accounting to its financial statements because (i) the holders of existing voting shares of the Company prior to its emergence received less than 50% of the voting shares of the Company outstanding following its emergence from bankruptcy and (ii) the reorganization value of the Company’s assets immediately prior to confirmation of the plan of reorganization was less than the post-petition liabilities and allowed claims. The Company elected to apply fresh start accounting effective October 1, 2016, to coincide with the timing of its normal fourth quarter reporting period, which resulted in SandRidge becoming a new entity for financial reporting purposes. The Company evaluated and concluded that events between October 1, 2016 and October 4, 2016 were immaterial and use of an accounting convenience date of October 1, 2016 was appropriate. As such, fresh start accounting is reflected in the accompanying consolidated balance sheet as of December 31, 2016 and related fresh start adjustments are included in the accompanying statement of operations for the period from January 1, 2016 through October 1, 2016 (the “Predecessor 2016 Period”). As a result of the application of fresh start accounting and the effects of the implementation of the Plan, the financial statements for the period after October 1, 2016 (the “Successor 2016 Period”) will not be comparable with the financial statements prior to that date. References to the “Successor” or the “Successor Company” relate to SandRidge subsequent to October 1, 2016. References to the “Predecessor” or “Predecessor Company” refer to SandRidge on and prior to October 1, 2016. Reorganization Value. Reorganization value represents the fair value of the Successor Company’s total assets and is intended to approximate the amount a willing buyer would pay for the assets immediately after restructuring. Under fresh start accounting, the Company allocated the reorganization value to its individual assets based on their estimated fair values. The Company’s reorganization value is derived from an estimate of enterprise value. Enterprise value represents the estimated fair value of an entity’s long term debt and other interest-bearing liabilities and shareholders’ equity. In support of the Plan, the Company estimated the enterprise value of the Successor Company to be in the range of $1.04 billion to $1.32 billion , which was subsequently approved by the Bankruptcy Court. This valuation analysis was prepared using reserve information, development schedules, other financial information and financial projections, third-party real estate reports, and applying standard valuation techniques, including net asset value analysis, precedent transactions analyses and public comparable company analyses. Based on the estimates and assumptions used in determining the enterprise value, the Company estimated the enterprise value to be approximately $1.09 billion . Valuation of Oil and Gas Properties. The Company’s principal assets are its oil and gas properties, which are accounted for under the Full Cost Accounting method as described in Note 3. With the assistance of valuation experts, the Company determined the fair value of its oil and gas properties based on the discounted cash flows expected to be generated from these assets. The computations were based on market conditions and reserves in place as of the bankruptcy emergence date. The fair value analysis performed by valuation experts was based on the Company’s estimates of proved reserves as developed internally by the Company’s reserves engineers. Discounted cash flow models were prepared using the estimated future revenues and development and operating costs for all developed wells and undeveloped locations comprising the proved reserves. Future revenues were based upon forward strip oil and natural gas prices as of the emergence date, adjusted for differentials realized by the Company. Development and operating costs from proved reserves estimates were adjusted for inflation. A risk adjustment factor was applied to the proved undeveloped reserve category. The discounted cash flow models also included estimates not typically included in proved reserves such as depreciation and income tax expenses. The risk adjusted after tax cash flows were discounted at 10% . This discount factor was derived from a weighted average cost of capital computation which utilized a blended expected cost of debt and expected returns on equity for similar industry participants. From this analysis the Company concluded the fair value of its proved reserves was $632.8 million as of the Emergence Date. The Company also reviewed its undeveloped leasehold acreage and concluded that the fair value of undeveloped leasehold acreage was $113.9 million based on analysis of comparable market transactions. These amounts are reflected in the Fresh Start Adjustments item number 14 below. The following table reconciles the enterprise value to the estimated fair value of the Successor Company's common stock as of the Emergence Date (in thousands, except per share amounts): Enterprise value $ 1,089,808 Plus: Cash and cash equivalents 563,372 Less: Fair value of New Building Note (36,610 ) Less: Asset retirement obligation (92,412 ) Less: Fair value of New First Lien Exit Facility (414,954 ) Less: Fair value of New Convertible Notes (445,660 ) Less: Fair value of warrants, including warrants held in reserve for settlement of general unsecured claims (95,794 ) Fair value of Successor common stock issued upon emergence $ 567,750 Shares issued upon emergence on October 4, 2016, including shares held in reserve for settlement of general unsecured claims 19,371 Per share value $ 29.31 The following table reconciles the enterprise value to the estimated reorganization value as of the Emergence Date (in thousands): Enterprise value $ 1,089,808 Plus: cash and cash equivalents 563,372 Plus: other working capital liabilities 131,766 Plus: other long-term liabilities 8,549 Reorganization value of Successor assets $ 1,793,495 Reorganization value and enterprise value were estimated using numerous projections and assumptions that are inherently subject to significant uncertainties and resolution of contingencies that are beyond our control. Accordingly, the estimates included in this report are not necessarily indicative of actual outcomes, and there can be no assurance that the estimates, projections or assumptions will be realized. Consolidated Balance Sheet. The adjustments included in the following consolidated balance sheet reflect the effects of the transactions contemplated by the Plan and carried out by the Company on the Emergence Date (reflected in the column “Reorganization Adjustments”) as well as fair value adjustments as a result of the adoption of fresh start accounting (reflected in the column “Fresh Start Adjustments”). The explanatory notes highlight methods used to determine fair values or other amounts of the assets and liabilities as well as significant assumptions. The following table reflects the reorganization and application of Accounting Standards Codification (“ASC”) 852 “Reorganizations” on the consolidated balance sheet as of October 1, 2016 (in thousands): Predecessor Company Reorganization Adjustments Fresh Start Adjustments Successor Company ASSETS Current assets Cash and cash equivalents $ 652,680 $ (142,148 ) (1) $ — $ 510,532 Restricted cash - collateral — 50,000 (2) — 50,000 Restricted cash - other — 2,840 (2) — 2,840 Accounts receivable, net 61,446 12,356 (3) — 73,802 Derivative contracts 10,192 — (669 ) (12) 9,523 Prepaid expenses 12,514 (8,218 ) (4) — 4,296 Other current assets 1,003 — 3,217 (13) 4,220 Total current assets 737,835 (85,170 ) 2,548 655,213 Oil and natural gas properties, using full cost method of accounting Proved 12,093,492 — (11,344,684 ) (14) 748,808 Unproved 322,580 — (205,578 ) (14) 117,002 Less: accumulated depreciation, depletion and impairment (11,637,538 ) — 11,637,538 (14) — 778,534 — 87,276 865,810 Other property, plant and equipment, net 357,528 (41 ) (93,782 ) (15) 263,705 Derivative contracts 70 — (70 ) (12) — Other assets 12,537 (3,770 ) (5) — 8,767 Total assets $ 1,886,504 $ (88,981 ) $ (4,028 ) $ 1,793,495 Predecessor Company Reorganization Adjustments Fresh Start Adjustments Successor Company LIABILITIES AND STOCKHOLDERS’ (DEFICIT) EQUITY Current liabilities Accounts payable and accrued expenses $ 140,448 $ (14,820 ) (6) $ — $ 125,628 Derivative contracts 2,982 — 1,666 (12) 4,648 Asset retirement obligations 8,573 — 57,105 (16) 65,678 Total current liabilities 152,003 (14,820 ) 58,771 195,954 Long-term debt — 731,735 (7) 1,610 (17) 733,345 Derivative contracts 935 — 304 (12) 1,239 Asset retirement obligations 62,896 — (36,161 ) (16) 26,735 Other long-term obligations 3 8,798 (8) (3 ) 8,798 Liabilities subject to compromise 4,346,188 (4,346,188 ) (9) — — Total liabilities 4,562,025 (3,620,475 ) 24,521 966,071 Equity SandRidge Energy, Inc. stockholders’ equity (deficit) Predecessor preferred stock 6 — (6 ) (18) — Predecessor common stock 718 — (718 ) (18) — Predecessor additional paid-in capital 5,315,655 — (5,315,655 ) (18) — Predecessor additional paid-in capital—stockholder receivable (1,250 ) 1,250 (10) — — Predecessor treasury stock, at cost (5,218 ) — 5,218 (18) — Successor common stock — 19 (11) — 19 Successor warrants — 88,382 (11) — 88,382 Successor additional paid-in capital — 739,023 (11) — 739,023 Accumulated deficit (7,985,411 ) 2,702,820 (9) 5,282,591 (19) — Total SandRidge Energy, Inc. stockholders’ (deficit) equity (2,675,500 ) 3,531,494 (28,570 ) 827,424 Noncontrolling interest (21 ) — 21 (20) — Total stockholders’ (deficit) equity (2,675,521 ) 3,531,494 (28,549 ) 827,424 Total liabilities and stockholders’ equity (deficit) $ 1,886,504 $ (88,981 ) $ (4,028 ) $ 1,793,495 Reorganization Adjustments 1. Reflects the net cash payments made upon emergence (in thousands): Sources: Proceeds from New Building Note $ 26,847 Total sources $ 26,847 Uses and transfers: Cash transferred to restricted accounts (collateral and general unsecured claims) $ 52,840 Payments and funding of escrow account related to professional fees 43,770 Payment on Senior Credit facility (principal and interest) 35,238 Repayment of Senior Secured Notes and Unsecured Notes 33,874 Payment of certain contract cures and other 3,273 Total uses and transfers 168,995 Net uses and transfers $ (142,148 ) 2. Funding of $50.0 million Cash Collateral account and the funding of $2.8 million to be held in reserve by the Company for distribution to satisfy allowed general unsecured claims as specified under the Plan. 3. Accrual for future reimbursement of the unused portion of the professional fees escrow account and other receivables. 4. Write-off of prepaid expenses primarily related to $7.5 million of prepaid premium for the Predecessor Company’s directors and officers insurance policy. 5. Application of a $3.8 million deposit held by a utility service toward the settlement of the utility service’s claims under the Plan. 6. Includes a $43.8 million decrease in accrued liabilities as a result of funding an escrow account established for the payment of professional fees, partially offset by the reinstatement of certain liabilities subject to compromise as accounts payable and accrued expenses. 7. Principal balances of $35.0 million of the New Building Note, $281.8 million of the New Convertible Notes, and the $415.0 million drawn on the New First Lien Exit Facility. 8. Reclassification of non-qualified deferred compensation plan and gas balancing liabilities from liabilities subject to compromise to other long term obligations, as these liabilities became obligations of the Successor. 9. Liabilities subject to compromise were settled as follows in accordance with the Plan (in thousands): Current maturities of long-term debt and accrued interest $ 4,179,483 Accounts payable and accrued expenses 157,422 Other long-term liabilities 9,283 Liabilities subject to compromise of the Predecessor 4,346,188 Cash payments at emergence (72,385 ) Cash proceeds from building mortgage 26,847 Write-off of prepaid accounts upon emergence (8,218 ) Accrual for future reimbursement from professional fees escrow account and other receivables 12,356 Total consideration given pursuant to the Plan: Fair value of equity issued (827,424 ) Principal value of long-term debt issued and reinstated at emergence (731,735 ) Reinstatement of liabilities subject to compromise as accounts payable and accrued expenses (37,789 ) Release of stockholder receivable (1,250 ) Application of deposit held by utility services (3,770 ) Gain on settlement of liabilities subject to compromise $ 2,702,820 10. Release of a receivable from the Predecessor’s former director and officer as outlined in the Plan. 11. The following table reconciles reorganization adjustments made to Successor common stock, warrants and additional paid in capital (in thousands): Par value of 18.9 million shares of New Common Stock issued to former holders of the Senior Secured Notes and Unsecured Notes (valued at $29.31 per share) $ 19 Fair value of warrants issued to holders of the Unsecured Notes(1) 88,382 Additional paid in capital - New Common Stock 575,144 Additional paid in capital - premium on New Convertible Notes(2) 163,879 Total Successor Company equity issued on Emergence Date $ 827,424 ____________________ (1) The fair value of the warrants was estimated using a Black-Scholes-Merton model with the following assumptions: implied stock price of the Successor Company; exercise price per share of $41.34 and $42.03 for Warrant classes A and B, respectively; expected volatility of 59.26% ; risk free interest rate, continuously compounded, of 1.36% ; and holding period of six years. (2) The fair value of the New Convertible Notes was estimated using a Monte Carlo simulation with the following assumptions; the implied Successor Company stock price; expected volatility of 56.06% ; risk free interest rate, continuously compounded, of 1.08% ; recovery rate of 15.00% ; hazard rate of 12.41% ; drop on default of 100.00% ; and termination period after four years. The premium is the difference between the fair value of the New Convertible Notes of $445.7 million and the principal value of the New Convertible Notes of $281.8 million . Fresh Start Adjustments 12. Adjustments and reclassifications of derivative contracts based on their Emergence Date fair values, which were determined using the fair value methodology for commodity derivative contracts discussed in Note 6. 13. Fair value adjustment to other current assets to record assets held for sale at their anticipated sales prices. 14. Fair value adjustments to oil and natural gas properties, including asset retirement obligation, associated inventory, unproved acreage and seismic. See above for detailed discussion of fair value methodology. 15. Adjustments to other property, plant and equipment to record the assets at their respective fair values on the Emergence Date. A combination of the cost approach and income approach were utilized to determine the fair values of the Company’s headquarters and other properties located in downtown Oklahoma City, Oklahoma, and the cost approach was utilized to determine the fair value of all other property, plant and equipment. 16. Fair value adjustments to the Company’s asset retirement obligations as a result of applying fresh start accounting. Upon implementation of fresh start accounting, the Company revalued these obligations based upon updates to wells’ productive lives and application of the Successor Company’s credit adjusted risk fee rate. 17. Fair value adjustment to record premium on the New Building Note. 18. Cancellation of Predecessor Company’s common stock, preferred stock, treasury stock and paid-in capital. 19. Adjustment to reset retained deficit to zero . 20. Elimination of the Predecessor non-controlling interest. Reorganization Items Reorganization items represent liabilities settled, net of amounts incurred subsequent to the Chapter 11 filing as a direct result of the Plan and are classified as gain on reorganization items, net in the accompanying consolidated statement of operations. The following table summarizes reorganization items for the Predecessor 2016 Period (in thousands): Unamortized long-term debt $ 3,546,847 Litigation claims (20,478 ) Rejections and cures of executory contracts (16,038 ) Ad valorem and franchise taxes (3,494 ) Legal and professional fees and expenses (44,920 ) Write off of director and officer insurance policy (7,533 ) Gain on accounts payable settlements 84,228 Loss on mortgage (8,153 ) Gain on preferred stock dividends 37,893 Fresh start valuation adjustments (28,549 ) Fair value of equity issued (827,424 ) Principal value of New Convertible Notes issued (281,780 ) Gain on reorganization items, net $ 2,430,599

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Fresh Start Accounting. Upon emergence from bankruptcy the Company adopted fresh start accounting. See Note 2 for further details. Nature of Business. SandRidge Energy, Inc. is an oil and natural gas company with a principal focus on exploration and production activities in the Mid-Continent and Rockies regions of the United States. The Company’s Rockies properties were acquired during the fourth quarter of 2015. Additionally, the Company owned interests in the Gulf of Mexico and Gulf Coast until February 2014, as discussed in Note 5 . Principles of Consolidation. The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern, which contemplates continuity of operations, realization of assets and satisfaction of liabilities in the normal course of business. The consolidated financial statements include the accounts of the Company and its wholly owned or majority owned subsidiaries. During the years ended December 31, 2015, and 2014, the Company fully consolidated the activities of each the SandRidge Mississippian Trust I (the “Mississippian Trust I”), SandRidge Mississippian Trust II (the “Mississippian Trust II”) and SandRidge Permian Trust (the “Permian Trust”) (each individually, a “Royalty Trust” and collectively, the “Royalty Trusts”) as variable interest entities (“VIEs”) for which the Company was the primary beneficiary. Activities of the Royalty Trusts attributable to third party ownership were presented as noncontrolling interest and included as a component of equity in the condensed consolidated balance sheet as of December 31, 2015 . As discussed further below, during the year ended December 31, 2016 , the Company proportionately consolidated the activities of the Royalty Trusts. All significant intercompany accounts and transactions have been eliminated in consolidation. 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 natural gas liquids (“NGL”) reserves; 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. Restricted Cash. The Company maintains restricted escrow funds as required by certain contractual arrangements in accordance with the Plan. 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, which have a contractual maturity of one year or less. 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. As part of fresh start accounting, the allowance for doubtful accounts was reset to zero on the Emergence Date. Refer to Note 7 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 6 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. Fair value measurements for the electrical asset were based on replacement cost. Inputs used in the cost approach are based on the cost to a market participant buyer to acquire or construct a substitute asset of comparable utility, adjusted for inutility. 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 6 . 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. 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 12 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 during the Successor 2016 Period of $4.0 million and the Predecessor Company capitalized internal costs of $22.7 million , $45.1 million and $55.4 million to the full cost pool during the Predecessor 2016 Period and the years ended December 31, 2015 and 2014 , 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, electrical infrastructure, 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 2 to 30 years for equipment. When property and equipment components are disposed, the cost and the related accumulated depreciation are removed and any resulting gain or loss is reflected in the consolidated statements of operations. As part of fresh start accounting, property, plant and equipment were adjusted to their estimated fair value and depreciable lives were revised as of October 1, 2016, as described in Note 2 . 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. Impairment is measured as the excess of the carrying amount of the impaired asset or asset group over its fair value. See Note 9 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 the Predecessor 2016 Period and years ended December 31, 2015 and 2014 , the Predecessor Company capitalized interest of approximately, $2.2 million , $10.8 million and $14.7 million , respectively, on unproved properties that were not currently being depreciated or depleted and on which exploration activities were in progress. Additionally, the Predecessor Company capitalized interest of $3.3 million and $5.0 million in 2015 and 2014 , respectively, on midstream and corporate assets which were under construction. Debt Issuance Costs. The Company includes unamortized line-of-credit debt issuance costs, if any, related to its credit facility in other assets in the consolidated balance sheets. Other debt issuance costs related to long-term debt, if any, are presented in the balance sheets as a direct deduction from the associated debt liability. Debt issuance costs are amortized to interest expense over the scheduled maturity period of the related debt. 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 relate primarily to the Company’s non-qualified deferred compensation plan, and have been designated as available for sale and measured at fair value using quoted prices readily available in the market pursuant to the fair value option which requires unrealized gains and losses be reported in earnings. Investments are included in other current assets and other assets in the accompanying consolidated balance sheets. 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 13 for further discussion of the Company’s asset retirement obligations. As part of fresh start accounting, the ARO liabilities were adjusted to their estimated fair value as described in Note 2 . 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. Additionally, the Successor Company has made an accounting policy election to deduct transportation costs from oil, natural gas and NGL revenues. This resulted in presenting $7.4 million of transportation costs as a reduction from revenues in the Successor 2016 Period versus the presentation of $26.2 million , $45.3 million and $35.6 million of these costs as production expenses in the Predecessor 2016 Period, and the years ended December 31, 2015 and 2014, respectively. and 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 $1.7 million and $1.5 million at December 31, 2016 and 2015 , respectively. The Company includes the gas imbalance positions in other long-term obligations in the consolidated balance sheets. For the years ended December 31, 2015 and 2014, the Company recognized revenues and expenses generated from daywork and footage drilling contracts as the services were performed since the Company did not bear the risk of completion of the well. The Company received 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 were recognized at the time mobilization services were performed. Revenues and expenses related to drilling and services are included in other revenue and expense in the accompanying consolidated statements of operations for the years ended December 31, 2015 and 2014. In general, natural gas purchased and sold by the midstream business was priced at a published daily or monthly index price. Sales to wholesale customers typically incorporated a premium for managing their transmission and balancing requirements. Midstream services revenues were recognized upon delivery of natural gas to customers and/or when services were rendered, pricing was determined and collectability was reasonably assured. Revenues from third-party midstream services were presented on a gross basis, since the Company acted as a principal by taking ownership of the natural gas purchased and taking responsibility of fulfillment for natural gas volumes sold. Revenues and expenses related to midstream and marketing are included in other revenue and expense in the accompanying consolidated statements of operations for the years ended December 31, 2015 and 2014. Allocation of Share-Based Compensation. For both the Successor and Predecessor Companies, equity compensation provided to employees directly involved in exploration and development activities is capitalized to the Company’s oil and natural gas properties. Equity compensation not capitalized is recognized in general and administrative expenses, production expenses, and other operating expense in the accompanying consolidated statements of operations. 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 Successor Company consist of unvested restricted stock awards and warrants, using the treasury method, and convertible senior notes, using the if-converted method. Potentially dilutive securities for the Predecessor Company 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 or the proceeds that would be received if the warrants were exercised are assumed to be used to repurchase shares at the average market price. Under the if-converted method, the Successor Company assumes the conversion of the New Convertible Notes to common stock and determines if it is more dilutive than including the expense associated with the New Convertible Notes in the computation of income available to common stockholders. Under the if-converted method, the Predecessor Company assumed the conversion of the preferred stock or Convertible Senior Unsecured Notes to common stock and determined if it was more dilutive than including the preferred stock dividends or expense associated with the Convertible Senior Unsecured 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 19 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 14 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 New First Lien Exit Facility constitutes a default under its commodity derivative contracts with counterparties that are lenders under the New First Lien Exit 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 for like commodities and derivative instruments 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 First Lien Exit Facility can be offset against amounts owed, if any, to such counterparty under the Company’s First Lien Exit 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. 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. The Company had sales exceeding 10% of total revenues to the following oil and natural gas purchasers (in thousands): Sales % of Revenue Period from October 2, 2016 through December 31, 2016 - Successor Targa Pipeline Mid-Continent West OK LLC $ 35,845 36.4 % Plains Marketing, L.P. $ 32,022 32.5 % Period from January 1, 2016 through October 1, 2016 - Predecessor Plains Marketing, L.P. $ 110,370 37.6 % Targa Pipeline Mid-Continent West OK LLC $ 108,238 36.8 % December 31, 2015 - Predecessor Plains Marketing, L.P. $ 318,018 41.4 % Targa Pipeline Mid-Continent West OK LLC $ 231,649 30.1 % December 31, 2014 - Predecessor Plains Marketing, L.P. $ 597,117 38.3 % Targa Pipeline Mid-Continent West OK LLC $ 333,027 21.4 % Recent Accounting Pronouncements. The Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”) 2015-02, “Amendments to the Consolidation Analysis,” which 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 were effective for annual reporting periods beginning January 1, 2016 for the Company, including interim periods within that reporting period, with early adoption permitted. The Company adopted this guidance on January 1, 2016, which resulted in the determination that the Royalty Trusts no longer qualify as VIEs. As a result, the Successor and Predecessor Companies proportionately consolidated the activities of the Royalty Trusts in 2016. Under the proportionate consolidation method, the Company accounts for only its share of each Royalty Trust’s asset, liabilities, revenues and expenses within the appropriate classifications in the accompanying consolidated financial statements. The Company adopted the provisions of ASU 2015-02 on a modified retrospective approach by recording a cumulative-effect adjustment as of January 1, 2016 that resulted in decreases of approximately $243.4 million to total assets and approximately $510.2 million to noncontrolling interest and increases of approximately $9.7 million to accounts payable and approximately $257.1 million to retained earnings. These adjustments had no impact on prior period balances. The FASB issued ASU 2015-03, "Interest-Imputation of Interest (Topic 835): Simplifying the Presentation of Debt Issuance Costs," which requires debt issuance costs related to a recognized debt liability to be presented on the balance sheet as a direct deduction from the carrying amount of that debt liability rather than as an asset. The guidance was adopted on January 1, 2016, and resulted in a decrease of approximately $69.1 million to other assets and current maturities of long-term debt in the accompanying consolidated balance sheet for the year ended December 31, 2015, with no impact to the accompanying consolidated statements of operations. See Note 11 for treatment and classification of unamortized debt issuance costs subsequent to filing the Chapter 11 petitions. In August 2015, the FASB issued ASU 2015-15, “Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements,” which excludes line-of-credit debt issuance costs from the scope of ASU 2015-03. The guidance was adopted on January 1, 2016 in conjunction with the adoption of ASU 2015-03. The Company made an accounting policy election to present line-of-credit arrangement debt issuance costs as an asset and subsequently amortize the deferred debt issuance costs ratably over the term of the line-of-credit arrangement. The adoption of this ASU resulted in no impact to the consolidated financial statements. The FASB issued ASU 2014-15, “Presentation of Financial Statements - Going Concern (Subtopic 205-40): 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.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2016
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 (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Supplemental Disclosure of Cash Flow Information Cash paid for reorganization items $ — $ (55,606 ) $ — $ — Cash paid for interest, net of amounts capitalized $ (1,183 ) $ (104,609 ) $ (296,386 ) $ (235,793 ) Cash (paid) received for income taxes $ — $ (28 ) $ (88 ) $ 1,928 Supplemental Disclosure of Noncash Investing and Financing Activities Cumulative effect of adoption of ASU 2015-02 $ — $ (247,566 ) $ — $ — Property, plant and equipment transferred in settlement of contract $ — $ 215,635 $ — $ — Change in accrued capital expenditures $ 10,630 $ 25,045 $ 177,586 $ (55,557 ) Equity issued for debt $ (13,001 ) $ (4,409 ) $ (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, 2016
Acquisitions And Dispositions [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures Predecessor Acquisitions and Divestitures 2016 Divestiture Divestiture of West Texas Overthrust 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 West Texas Overthrust (“WTO”) to Occidental Petroleum Corporation (“Occidental”) and was released from all past, current and future claims and obligations under an existing 30 year treating agreement between the companies. As of the date of the transaction, the Company had accrued approximately $111.9 million for penalties associated with shortfalls in meeting its delivery requirements under the agreement since it became effective in late 2012. The Company recognized a loss of approximately $89.1 million on the termination of the treating agreement and the cease-use of transportation agreements that supported production from the Piñon field and reduced its asset retirement obligations associated with its oil and natural gas properties by $34.1 million . 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 PGC for $48.0 million in cash and $78.0 million principal amount of newly issued PGC Senior Secured Notes. PGC owned approximately 370 miles of gathering lines supporting the natural gas production from the Company's Piñon field in the 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 ). 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 (collectively, 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 20 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. See Note 6 for additional discussion of the determination of the guarantee’s fair value. The guarantee did not limit the Company’s potential future payment obligations; 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 company recorded revenues and expenses of $90.9 million and $63.7 million , respectively, through the date of the sale, including direct operating expenses, depletion, accretion of asset retirement obligations and general and administrative expenses, for the Gulf Properties which are included in the Predecessor Company’s accompanying consolidated statement of operations for the year ended December 31, 2014.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2016
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, 2016 and 2015 , 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 current assets and 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 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 as discussed in Note 5 . The PGC Senior Secured Notes were issued at a substantial discount, as discussed in Note 11 and Note 12 , which resulted in the treatment of the mandatory prepayment feature as an embedded derivative that met the criteria to be bifurcated from its host contract and accounted for separately from the PGC Senior Secured Notes. Prior to Chapter 11 filings, the mandatory prepayment feature was 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. Subsequent to the Chapter 11 filings in May 2016, the value of the mandatory repayment feature of $2.5 million was written off and is included in reorganization items in the accompanying consolidated statement of operations for the Predecessor 2016 Period. Level 3 Fair Value Measurements Commodity Derivative Contracts. The Company had natural gas basis swaps outstanding on the Emergence Date and at December 31, 2015 and 2014. The fair value of the natural gas basis swaps was 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 the commodity derivative contracts. The significant unobservable input that was used in the fair value measurement of the Company’s natural gas basis swaps was the estimate of future natural gas basis differentials. The fair value of the natural gas basis swaps and any purchases, gains/losses and settlements were insignificant for the Predecessor 2016 Period and for the years ended December 31, 2015 and 2014. No natural gas basis swaps were outstanding at December 31 2016. Debt Holder Conversion Feature . The Predecessor Company’s Convertible Senior Unsecured Notes each contained a conversion option whereby, prior to Chapter 11 filings, the Convertible Senior Unsecured Notes holders had the option to convert the notes into shares of Company common stock. These conversion features were identified as embedded derivatives that met the criteria to be bifurcated from their host contracts and accounted for separately from the Convertible Senior Unsecured Notes. Subsequent to the Chapter 11 filings, the value of the debt holder conversion feature of $7.3 million was written off and is included in reorganization items in the accompanying statement of operations for the Predecessor 2016 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 was the hazard rate, an estimate of default probability. Th e 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) Debt conversion feature hazard rate 114.0 % – 135.2 % 119.2 % $ 29,355 See further discussion of the Convertible Senior Unsecured Notes at Note 11 . Guarantee. The Company guaranteed on behalf of Fieldwood certain plugging and abandonment obligations associated with the sale of its Gulf Properties from the date of closing until the Company was released from the guarantee in the third quarter of 2015. 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. 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 5 for discussion of the sale of the Gulf Properties. The fair value of the guarantee and any issuances and settlements were insignificant for the year ended December 31, 2014. 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, 2016 - Successor Fair Value Measurements Netting(1) Assets/Liabilities at Fair Value Level 1 Level 2 Level 3 Assets Investments $ 7,541 $ — $ — $ — $ 7,541 $ 7,541 $ — $ — $ — $ 7,541 Liabilities Commodity derivative contracts $ — $ 29,714 $ — $ — $ 29,714 $ — $ 29,714 $ — $ — $ 29,714 December 31, 2015 - Predecessor 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 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 ____________________ (1) Represents the impact of netting assets and liabilities with counterparties where the right of offset exists. Level 3 - Debt Holder Conversion Feature. The table below sets forth a reconciliation of the Company’s Level 3 fair value measurements for debt holder conversion features (in thousands): Predecessor Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Beginning balance $ 29,355 $ — Issuances — 31,200 (Loss) gain on derivative holder conversion feature (880 ) 10,198 Conversions (21,194 ) (12,043 ) Write off of derivative holder conversion feature to reorganization items (7,281 ) — Ending level 3 debt holder conversion feature balance $ — $ 29,355 Prior to commencement of the Chapter 11 Proceedings, the fair values of the conversion features were determined quarterly with changes in fair value recorded as interest expense. 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, 2016 , 2015 and 2014 , 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 Successor Company measures the fair value of its New Convertible Notes using pricing that was readily available in the public market at December 31, 2016. The Successor Company measures the fair value of its New Building Note using a discounted cash flow analysis. The Predecessor Company also measured the fair value of its Senior Secured Notes and the Unsecured Notes using pricing that was 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 notes are as follows (in thousands): Successor Predecessor December 31, 2016 December 31, 2015 Fair Value Carrying Value Fair Value Carrying Value New Convertible Notes $ 334,800 $ 268,780 $ — $ — New Building Note $ 40,608 $ 36,528 $ — $ — 8.75% Senior Secured Notes due 2020 $ — $ — $ 403,098 $ 1,265,814 Senior Unsecured Notes 8.75% Senior Notes due 2020 $ — $ — $ 39,740 $ 389,232 7.5% Senior Notes due 2021 $ — $ — $ 79,812 $ 751,087 8.125% Senior Notes due 2022 $ — $ — $ 57,749 $ 518,693 7.5% Senior Notes due 2023 $ — $ — $ 58,799 534,869 Convertible Senior Unsecured Notes 8.125% Convertible Senior Notes due 2022 $ — $ — $ 44,199 $ 78,290 7.5% Convertible Senior Notes due 2023 $ — $ — $ 15,125 $ 24,393 See Note 1 for additional information regarding the bankruptcy proceedings and Note 11 for discussion of the Company’s long-term debt. Fair Value of Non-Financial Assets and Liabilities See Note 2 for additional information regarding fair value adjustments for non-financial assets and liabilities resulting from the application of fresh start accounting and Note 9 for discussion of the Company’s impairment valuations.

Accounts Receivable

Accounts Receivable	12 Months Ended
	Dec. 31, 2016
Receivables [Abstract]
Accounts Receivable	Accounts Receivable A summary of accounts receivable is as follows (in thousands): Successor Predecessor December 31, December 31, 2016 2015 Oil, natural gas and NGL sales $ 42,631 $ 61,140 Joint interest billing 17,338 60,403 Oil and natural gas services 736 2,417 Other 14,272 8,274 Total accounts receivable 74,977 132,234 Less: allowance for doubtful accounts (880 ) (4,847 ) Total accounts receivable, net $ 74,097 $ 127,387 The following table presents the balance and activity in the allowance for doubtful accounts for the Successor 2016 Period, the Predecessor 2016 Period and years ended December 31, 2015 and 2014 (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Beginning balance $ — $ 4,847 $ 7,083 $ 11,061 Additions charged to costs and expenses(1) 880 16,695 1,320 818 Deductions(2) — (751 ) (3,556 ) (4,796 ) Impact of fresh start accounting — (20,791 ) — — Ending balance $ 880 $ — $ 4,847 $ 7,083 ____________________ (1) The Predecessor 2016 Period includes an addition for a joint interest account receivable after a determination that future collection was doubtful. (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, 2016
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment consists of the following (in thousands): Successor Predecessor December 31, December 31, 2016 2015 Oil and natural gas properties Proved(1) $ 840,201 $ 12,529,681 Unproved 74,937 363,149 Total oil and natural gas properties 915,138 12,892,830 Less accumulated depreciation, depletion and impairment (353,030 ) (11,149,888 ) Net oil and natural gas properties capitalized costs 562,108 1,742,942 Land 5,100 14,260 Non-oil and natural gas equipment(2) 166,010 373,687 Buildings and structures(3) 88,603 227,673 Total 259,713 615,620 Less accumulated depreciation and amortization (3,889 ) (123,860 ) Other property, plant and equipment, net 255,824 491,760 Total property, plant and equipment, net $ 817,932 $ 2,234,702 ____________________ (1) No interest was capitalized for the Successor 2016 Period. Includes cumulative capitalized interest of approximately $48.9 million at December 31, 2015. (2) No interest was capitalized for the Successor 2016 Period. Includes cumulative capitalized interest of approximately $4.3 million at December 31, 2015. (3) No interest was capitalized for the Successor 2016 Period. Includes cumulative capitalized interest of approximately $20.4 million at December 31, 2015. In connection with the application of fresh start accounting as of October 1, 2016, the Company recorded fair value adjustments disclosed in Note 2 . Accumulated depreciation, depletion and impairment was therefore eliminated as of that date. Accumulated depreciation, depletion and impairment for the Predecessor Company oil and natural gas properties includes cumulative full cost ceiling limitation impairment of $8.2 billion at December 31, 2015. During the Successor 2016 Period the Successor Company reduced the net carrying value of its oil and natural gas properties by $319.1 million and for the Predecessor 2016 Period, the Predecessor Company reduced the net carrying value of its oil and natural gas properties by $657.4 million , as a result of quarterly full cost ceiling analyses in the respective periods. The Company reduced the net carrying value of its oil and natural gas properties by $4.5 billion and $164.8 million during the years ended December 31, 2015 and 2014 , respectively. See Note 9 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 $7.82 per Boe for the Successor 2016 Period, $5.76 per Boe for the Predecessor 2016 Period, $10.67 per Boe in 2015 and $15.00 per Boe in 2014 . 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. A portion of these assets were disposed of during the third quarter of 2015, resulting in a loss recorded in other operating expenses in the accompanying consolidated statement of operations of $3.5 million for the year ended December 31, 2015 . The remaining $16.0 million in assets held for sale at December 31, 2015 were sold during 2016, resulting in insignificant (loss) gain on sale of assets recorded for the Successor 2016 period and the Predecessor 2016 period. No significant assets were classified as held for sale at December 31, 2016. Drilling Carry Commitments During the year ended December 31, 2014, the Company was party to an agreement with Repsol E&P USA, Inc. (“Repsol”), which contained a carry commitment 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’s carry during the year ended December 31, 2014, which reduced the Company’s capital expenditures for the respective periods. Repsol fully funded its carry commitment in the third quarter of 2014. Under the terms of an amended agreement with Repsol, the Company committed to drill 484 net wells in an area of mutual interest and to carry Repsol’s future drilling and completion costs in the amount of $1.0 million for each committed well 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 and as a result, the Company was obligated under the agreement to carry a portion of Repsol’s drilling and completion costs totaling up to approximately $31.0 million for wells drilled after that time in the area of mutual interest. The Company incurred approximately $6.2 million and $16.1 million in costs toward this obligation for the Predecessor 2016 Period and the year ended December 31, 2015 , respectively. Effective June 6, 2016, the Bankruptcy Court issued orders allowing the Company to reject certain long-term contracts, including this drilling carry commitment. Repsol filed a bankruptcy claim for this commitment, which was settled by the Company for approximately $1.2 million . 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, 2016 (in thousands): Year Cost Incurred Total 2016 2015 2014 2013 and Prior Property acquisition $ 71,171 $ 7,390 $ 18,959 $ 34,770 $ 10,052 Exploration(1) 20,459 2,123 10,578 4,678 3,080 Total costs incurred $ 91,630 $ 9,513 $ 29,537 $ 39,448 $ 13,132 ____________________ (1) Includes $16.7 million of pipe inventory costs incurred ( $2.1 million in 2016 , $9.6 million in 2015 and $5.0 million in 2014 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, 2016
Asset Impairment Charges [Abstract]
Impairment	Impairment As deemed necessary based on events in 2016 , 2015 and 2014 , the Company analyzed various property, plant and equipment for impairment by comparing the carrying values of these assets to their estimated fair values. Estimated fair values of drilling, midstream, electrical transmission and other assets were determined in accordance with the policies discussed in Note 3. Impairment consists of the following (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Full cost pool ceiling limitation(1)(2)(3) $ 319,087 $ 657,392 $ 4,473,787 $ 164,779 Drilling assets(4) — 3,511 37,646 27,428 Electrical transmission assets(5) — 55,600 — — Midstream assets(6) — 1,691 7,148 561 Other(7) — — 16,108 — $ 319,087 $ 718,194 $ 4,534,689 $ 192,768 ____________________ (1) Impairment recorded in the Successor 2016 Period resulted from the application of fresh start accounting. Upon the application of fresh start accounting, the value of the Successor Company full cost pool was determined based upon forward strip oil and natural gas prices as of the Emergence Date. Because these prices were higher than the 12-month weighted average prices used in the full cost ceiling limitation calculation at December 31, 2016, the Successor Company incurred a ceiling test impairment. (2) Impairment recorded for the Predecessor Company in 2016 was due to full cost ceiling limitations recognized in each of the first three quarters of 2016. The impairments recorded in 2015 and the first two quarters of 2016 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 throughout 2015 and the first half of 2016. The impairment recorded in the third quarter of 2016 resulted primarily from downward revisions to forecasted reserves due to a decrease in projected Mid-Continent production volumes. (3) Impairment in 2014 resulted from the divestiture of the Gulf Properties. (4) Impairment recorded in the Predecessor 2016 Period and the year ended December 31, 2015, resulted from discontinued drilling operations in its Permian region which resulted in an impairment on certain drilling assets after determining their future use was limited. During 2014, the Company recorded a $24.3 million impairment on its drilling and oilfield services assets in the Permian region as a result of fulfilling its drilling obligation with the Permian Trust in 2014 and the downward trend in oil prices that began in the second half of 2014. (5) Impairment in the Predecessor 2016 Period resulted from a decrease in projected Mid-Continent production volumes supporting the system’s usage. (6) Impairment in the Predecessor 2016 Period and the years ended December 31, 2015 and 2014 resulted from the evaluation of certain midstream pipe inventory, natural gas compressors, gas treating plants and a carbon dioxide (“CO 2 ”) compressor station after determining that their future use was limited. (7) Impairment recorded on other assets in 2015, includes a $15.4 million impairment on property located in downtown Oklahoma City, Oklahoma to adjust the carrying value of the property to the agreed upon sales price for which it was later sold in 2016.

Accounts Payable and Accrued Ex

Accounts Payable and Accrued Expenses	12 Months Ended
	Dec. 31, 2016
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): Successor Predecessor December 31, December 31, 2016 2015 Accounts payable and other accrued expenses $ 65,408 $ 231,697 Accrued interest 648 73,320 Production payable 16,011 55,260 Payroll and benefits 33,606 42,728 Convertible perpetual preferred stock dividends — 21,572 Drilling advances 844 2,295 Related party — 1,545 Total accounts payable and accrued expenses $ 116,517 $ 428,417

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt consists of the following (in thousands): Successor Predecessor December 31, December 31, 2016 2015 New First Lien Exit Facility $ — $ — New Convertible Notes 268,780 — New Building Note 36,528 — Senior credit facility — — 8.75% Senior Secured Notes due 2020 — 1,265,814 Senior Unsecured Notes 8.75% Senior Notes due 2020 — 389,232 7.5% Senior Notes due 2021 — 751,087 8.125% Senior Notes due 2022 — 518,693 7.5% Senior Notes due 2023 — 534,869 Convertible Senior Unsecured Notes 8.125% Convertible Senior Notes due 2022 — 78,290 7.5% Convertible Senior Notes due 2023 — 24,393 Total debt 305,308 3,562,378 Less: current maturities of long-term debt — — Long-term debt $ 305,308 $ 3,562,378 On the Emergence Date, the balance outstanding under the senior credit facility of $449.2 million , par value of the Senior Secured Notes of $1.3 billion , par value of the Senior Unsecured Notes of $2.2 billion and par value of the Convertible Senior Unsecured Notes of $87.6 million were canceled upon emergence from bankruptcy and the Company entered into the New First Lien Exit Facility, issued New Convertible Notes and entered into the New Building Note as discussed further below. See Note 1 for additional information regarding the bankruptcy proceedings. See Note 6 for the fair values and carrying values of the long-term debt outstanding at December 31, 2016 and 2015 , respectively, and Note 2 for fresh start values calculated as of the Emergence Date. As of December 31, 2015 , there were no amounts outstanding under the senior credit facility, and the carrying values of the senior notes were net of unamortized discounts, premiums and deferred costs of $342.6 million , and included the fair value of debt derivatives of $32.3 million . A non-cash charge to write off all of the related unamortized debt issuance costs and associated discounts and premiums of approximately $158.6 million and the fair value of associated debt derivatives of $9.8 million as of May 16, 2016, is included in reorganization items in the accompanying consolidated statement of operations for the Predecessor 2016 Period, as discussed in Note 1 and Note 2. Successor Company Indebtedness New First Lien Exit Facility. As discussed in Note 1 , on the Emergence Date, the Company entered into the New First Lien Exit Facility with the lenders party thereto and Royal Bank of Canada, as administrative agent and issuing lender. The initial borrowing base under the New First Lien Exit Facility is $425.0 million . There are no scheduled borrowing base redeterminations until October 2018, followed by scheduled semiannual borrowing base redeterminations thereafter. The New First Lien Exit Facility matures on February 4, 2020. The outstanding borrowings under the New First Lien Exit Facility bear interest at a rate equal to, at the option of the Company, either (a) a base rate plus an applicable rate of 3.75% per annum or (b) LIBOR plus 4.75% per annum, subject to a 1.00% LIBOR floor. Interest on base rate borrowings is payable quarterly in arrears and interest on LIBOR borrowings is payable every one, two, three or six months, at the election of the Company. Quarterly, the Company pays commitment fees assessed at annual rates of 0.50% on any available portion of the New First Lien Exit Facility. The Company has the right to prepay loans under the New First Lien Exit Facility at any time without a prepayment penalty, other than customary “breakage” costs with respect to LIBOR loans. Furthermore, the New First Lien Exit Facility is secured by (i) first-priority mortgages on at least 95% of the PV-9 valuation of the proved developed producing reserves and 95% of the PV-9 valuation of all proved reserves included in the most recently delivered reserve report of the Company, (ii) a first-priority perfected pledge of capital stock of each credit party and their respective wholly owned subsidiaries and (iii) a first-priority security interest in the cash, cash equivalents, deposit, securities and other similar accounts, and a first-priority perfected security interest in substantially all other tangible and intangible assets of the credit parties (including but not limited to as-extracted collateral, accounts receivable, inventory, equipment, general intangibles, investment property, intellectual property, real property and the proceeds of the foregoing). The New First Lien Exit Facility requires the Company to, (a) commencing with the first full fiscal quarter ending after the Protected Period, maintain a minimum proved developing producing reserves asset coverage ratio, measured as of the last day of each fiscal quarter, of 1.75 to 1.00 and (b) commencing with the first full fiscal quarter ending after the occurrence of the end of the Protected Period, maintain (i) a maximum consolidated total net leverage ratio, measured as of the last day of each fiscal quarter, (A) on or prior to December 31, 2018, of no greater than 3.50 to 1.00, and (B) any fiscal quarter ending on or after March 31, 2019, of no greater than 3.00 to 1.00 and (ii) a minimum consolidated interest coverage ratio, measured as of the last day of each fiscal quarter, of no less than 2.00 to 1.00. Such financial covenants are subject to customary cure rights. The New First Lien Exit Facility contains customary affirmative and negative covenants, including compliance with laws (including environmental laws, ERISA and anti-corruption laws), maintenance of required insurance, delivery of quarterly and annual financial statements, oil and gas engineering reports, maintenance and operation of property (including oil and gas properties), restrictions on the incurrence of liens, indebtedness, asset dispositions, fundamental changes, restricted payments and other customary covenants. The Company had no amounts outstanding under the New First Lien Exit Facility at December 31, 2016 and $8.6 million in outstanding letters of credit, which reduce availability under the New First Lien Exit Facility on a dollar-for-dollar basis. The Company subsequently refinanced the New First Lien Exit Facility in February 2017. See Note 21 for additional discussion. New Convertible Notes. As discussed in Note 1, on the Emergence Date, pursuant to the terms of the Plan, the Company issued approximately $281.8 million principal amount of New Convertible Notes, which do not bear regular interest and will mature and mandatorily convert into New Common Stock on October 4, 2020, unless repurchased, redeemed or converted prior to that date. The New Convertible Notes were recorded at fair value of $445.7 million upon implementation of fresh start accounting. As the associated premium of $163.9 million was deemed significant to the principal amount of the New Convertible Notes, it was recorded in additional paid in capital in the consolidated balance sheet at December 31, 2016. Upon the occurrence of certain events, including any acceleration, repayment or prepayment of the New Convertible Notes (including any optional redemption), the Company will be required to pay a make-whole amount of $0.783478 for each $1.00 in principal amount of New Convertible Notes repaid or prepaid in accordance with the provisions of the associated indenture. The New Convertible Notes are initially convertible at a conversion rate of 0.05330841 shares of New Common Stock per $1.00 principal amount of New Convertible Notes, which represents, in the aggregate, approximately 15.0 million shares of the New Common Stock. The conversion rate for the New Convertible Notes is subject to customary anti-dilution adjustments. In addition, upon the occurrence of certain events, including any acceleration, repayment or prepayment of the New Convertible Notes (including any optional redemption), the conversion rate will be automatically adjusted such that the New Convertible Notes convert into the same percentage of New Common Stock before and after such event. The New Convertible Notes are convertible at the option of the holders at any time up to, and including, the business day immediately preceding the maturity date. In addition, the Company is required to convert all outstanding New Convertible Notes upon the earliest to occur of the following: (i) any bona fide arm’s length issuance by the Company of New Common Stock to third parties for cash with (a) a total issuance size that is greater than or equal to $100.0 million and (b) a per-share price greater than or equal to $34.16 ; (ii) 30 days’ written notice to the Company to convert the New Convertible Notes from holders of at least a majority in aggregate principal amount of the New Convertible Notes then outstanding; (iii) the average of the last reported sale prices of the New Common Stock over a 30 consecutive trading day period is 50% greater than $34.16 ; (iv) any bona fide refinancing of the New First Lien Exit Facility after a determination by the post-emergence board of directors in good faith that: (a) such refinancing provides for terms that are materially more favorable to the Company and (b) the causing of a conversion is not the primary purpose of such refinancing; (v) any change of control transaction; or (vi) the maturity date. Upon conversion, the Company will deliver shares of New Common Stock equal to the conversion rate, together with a cash payment in lieu of delivering any fractional share of New Common Stock issuable upon conversion, based on the last reported sale price of the New Common Stock on the relevant conversion date. During the Successor 2016 Period, holders of approximately $13.0 million in aggregate principal amount of the New Convertible Notes exercised conversion options applicable to those notes, resulting in the issuance of approximately 0.7 million shares of New Common Stock. The Company may redeem for cash all or part of the New Convertible Notes at any time prior to the maturity date, at a redemption price equal to 100% of the principal amount of such New Convertible Notes to be redeemed, as increased by the make-whole amount. With respect to any New Convertible Notes selected for redemption that are converted following a redemption notice, the conversion rate will be automatically adjusted such that the New Convertible Notes convert into the same percentage of New Common Stock before and after such redemption notice. The Company’s obligations pursuant to the New Convertible Notes are fully and unconditionally guaranteed, jointly and severally, by each of the Guarantors of the New First Lien Exit Facility. Following the occurrence of certain events, the Company would be required to secure $100.0 million of the New Convertible Notes, which amount may be increased to the full outstanding principal amount of the New Convertible Notes, including any applicable make-whole amount, in accordance with the provisions of the New Convertible Notes Indenture (the “Springing Lien”). The Springing Lien will be a second priority lien on the same collateral securing the New First Lien Exit Facility. The remaining outstanding New Convertible Notes were converted into shares of New Common Stock as a result of the Company’s entry into the refinanced credit facility on February 10, 2017, as discussed in Note 21 . New Building Note . As discussed in Note 1 , on the Emergence Date, the Company entered into the New Building Note, which has a principal amount of $35.0 million and is secured by first priority mortgage on the Company’s headquarters facility and certain other non-oil and gas real property. The New Building Note was recorded at fair value of $36.6 million upon implementation of fresh start accounting. Interest is payable on the New Building Note at 6% per annum for the first year following the Emergence Date, 8% per annum for the second year following the Emergence Date, and 10% thereafter through maturity. The effective interest rate was 10.9% for the New Building Note at December 31, 2016. Interest is payable in kind from the Emergence Date through the earlier of September 30, 2020, 46 months from the Emergence Date or 90 days after the refinancing or repayment of the New First Lien Exit Facility and thereafter in cash. The New Building Note matures on October 4, 2021. On the Emergence Date, pursuant to the Plan, certain holders of the Unsecured Senior Notes purchased the New Building Note for $26.8 million in cash, net of certain fees and expenses. Predecessor Company Indebtedness Senior Credit Facility. The terms of the senior credit facility contained certain financial covenants, including maintenance of agreed upon levels for the (a) ratio of total secured debt under the senior credit facility to earnings before interest, taxes, depreciation and amortization (“EBITDA”), which could not exceed 2.00 :1.00 at each quarter end and (b) ratio of current assets to current liabilities, which was required to 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 were included in current assets and unrealized assets and liabilities that resulted from mark-to-market adjustments on the Company’s commodity derivative contracts were disregarded. The senior credit facility matured by its terms 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 then outstanding notes. The senior credit facility also contained various covenants that limited 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. The terms of the senior credit facility allowed the Company to redeem or purchase outstanding Senior Unsecured Notes for up to $275.0 million in cash subject to certain limitations. Additionally, the senior credit facility limited the ability of the Company and certain of its subsidiaries to incur additional indebtedness with certain exceptions. The obligations under the senior credit facility were guaranteed by certain Company subsidiaries and were required to be 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, was determined by reference to (a) 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 was 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 was six months or longer, interest was paid at the end of each three-month period. Quarterly, the Company paid commitment fees assessed at annual rates of 0.5% on any available portion of the senior credit facility. 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 April 20, 2016, the Company submitted for consideration by its lenders additional properties to serve as collateral under the senior credit facility to support a borrowing base of $500.0 million . On May 11, 2016, in exchange for waivers from the requisite percentage of lenders with respect to certain specified defaults and events of defaults under the senior credit facility, the Company permanently repaid $40.0 million of borrowings to the lenders, which payment correspondingly reduced the lenders’ commitments. Senior Secured Notes. The Company issued $1.25 billion of 8.75% Senior Secured Notes due 2020 in June 2015. 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. Additionally, the Company issued $78.0 million par value of 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 , which included mandatory prepayment feature liabilities and a discount. Fair value at issuance was determined based upon the then-current market value of the Senior Secured Notes. The unamortized portions of the discount and the carrying value of the mandatory prepayment feature as of the date of the Chapter 11 filings, May 16, 2016, were written off to reorganization items on the accompanying consolidated statement of operations for the Predecessor 2016 Period as discussed in Note 1 . The Company accrued interest on its Senior Secured Notes at a fixed rate of 8.75% prior to the Chapter 11 filings, with no interest accrued subsequent to the filings. The Senior Secured Notes were by their terms redeemable, in whole or in part, prior to their maturity at specified redemption prices and were 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 were secured by second-priority liens on all of the Company’s assets that secured the senior credit facility on a first-priority basis; provided, however, the security interest in those assets that secured the Senior Secured Notes and the guarantees were contractually subordinated to liens thereon that secured the credit facility and certain other permitted indebtedness. Consequently, the Senior Secured Notes and the guarantees were effectively subordinated to the credit facility and such other indebtedness to the extent of the value of such assets. Pursuant to the indenture, the Senior Secured Notes by their terms matured 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 exceeded $100.0 million , the Senior Secured Notes would mature on October 16, 2019. See further discussion of the mandatory prepayment feature at Note 6 and Note 12 , which with respect to the PGC Senior Secured Notes was an embedded derivative that was accounted for separately from these notes, and was written off to reorganization items on the accompanying consolidated statement of operations for the Predecessor 2016 Period as discussed in Note 1 . The indenture governing the Senior Secured Notes contained covenants that restricted the Company’s ability to pay dividends, incur indebtedness, create liens, enter into consolidations or mergers, purchase or redeem stock or subordinated or unsecured indebtedness, dispose of or transfer certain assets, transact with related parties, make investments and refinance certain indebtedness, among other actions. These indentures were canceled upon the Company’s emergence from Chapter 11. See Note 1 for additional details about the Company’s Bankruptcy Petitions and the Chapter 11 proceedings. Senior Unsecured Notes. The Company accrued interest on its Senior Unsecured Notes at a fixed rate through the date of the Chapter 11 filings, with no interest accrued subsequent to the filings. Certain of the Senior Unsecured Notes were issued at a discount or a premium. Prior to the Chapter 11 filings, the discount or premium was amortized to interest expense over the term of the respective series of Senior Unsecured Notes. The unamortized portions of the discount or premium as of the date of the Chapter 11 filings, May 16, 2016, were written off to reorganization items on the accompanying consolidated statement of operations for the Predecessor 2016 Period as discussed in Note 1 . Each of the indentures governing the Company’s Senior Unsecured Notes contained covenants that restricted the Company’s ability to pay dividends, incur indebtedness, make investments, sell certain assets, purchase certain assets, transact with related parties and enter into consolidations or mergers. These indentures were canceled upon the Company’s emergence from Chapter 11. Convertible Senior Unsecured Notes. The Convertible Senior Unsecured Notes were issued in conjunction with exchanges and repurchases of Senior Unsecured Notes that took place in August and October 2015. 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. The Convertible Senior Unsecured Notes were guaranteed by the same Guarantors that guaranteed the Senior Unsecured Notes and were subject to covenants and bore 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 Company accrued interest on its Convertible Senior Unsecured Notes at a fixed rate through the date of the Chapter 11 filings, with no interest accrued subsequent to the filings. During the Predecessor 2016 Period, holders of $200.5 million aggregate principal amount ( $67.4 million net of discount and including holders’ conversion feature) of 8.125% Convertible Senior Notes due 2022 and $31.6 million aggregate principal amount ( $10.4 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 84.4 million shares of Company common stock and aggregate cash payments of $33.5 million for accrued interest and early conversion payments. The conversions resulted in a gain on extinguishment of debt totaling $41.3 million , including the write off of $4.3 million of net unamortized debt issuance costs, which is included in other income on the accompanying consolidated statement of operations for the Predecessor 2016 Period. 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, 2016 , $268.8 million of long-term debt will contractually mature in 2020 and $35.0 million , plus any unpaid interest on the New Building Note, will mature in 2021.

Derivatives

Derivatives	12 Months Ended
	Dec. 31, 2016
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 loss (gain) 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, 2016 , the Company’s commodity derivative contracts consisted of fixed price swaps under which 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. The Company recorded loss on commodity derivative contracts of $25.7 million and $4.8 million for the Successor 2016 Period and the Predecessor 2016 Period, respectively, as reflected in the accompanying consolidated statements of operations, which includes net cash receipts upon settlement of $7.7 million and $72.6 million , respectively. The net receipts for the Predecessor 2016 Period include settlements of contracts prior to their contractual maturity (“early settlements”) after the Chapter 11 filings occurred, resulting in $17.9 million of cash receipts. The Company recorded gain on commodity derivative contracts of $73.1 million and $334.0 million for the years ended December 31, 2015 and 2014 , respectively, as reflected in the accompanying consolidated statements of operations, which includes net cash (receipts) payments upon settlement of $(327.7) million and $32.3 million , respectively. Included in the net cash payments for 2014 are $69.9 million of cash payments related to early settlements primarily as a result of the sale of the Gulf Properties in February 2014. Derivatives Agreements with Royalty Trusts. During the years ended December 31, 2015 and 2014, 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. 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 by commodity type 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, 2016 , the counterparties to the Company’s open commodity derivative contracts consisted of four financial institutions, all of which are also lenders under the Company’s New First Lien Exit 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 New First Lien Exit Facility. 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 New First Lien Exit Facility and senior credit facility (in thousands): December 31, 2016 - Successor Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount Assets Derivative contracts - current $ — $ — $ — $ — $ — Derivative contracts - noncurrent — — — — — Total $ — $ — $ — $ — $ — Liabilities Derivative contracts - current $ 27,538 $ — $ 27,538 $ (27,538 ) $ — Derivative contracts - noncurrent 2,176 — 2,176 (2,176 ) — Total $ 29,714 $ — $ 29,714 $ (29,714 ) $ — December 31, 2015 - Predecessor 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 ) $ — At December 31, 2016 , the Company’s open commodity derivative contracts consisted of the following: Oil Price Swaps Notional (MBbls) Weighted Average Fixed Price January 2017 - December 2017 3,285 $ 52.24 January 2018 - December 2018 1,825 $ 55.34 Natural Gas Price Swaps Notional (MMcf) Weighted Average Fixed Price January 2017 - December 2017 32,850 $ 3.20 January 2018 - December 2018 3,650 $ 3.12 Predecessor Debt - Embedded Derivatives Debt Holder Conversion Feature. As discussed further in Note 6 and Note 11 , the Convertible Senior Unsecured Notes contained a conversion feature that was exercisable at the holders’ option. This conversion feature was identified as an embedded derivative as the feature (i) possessed economic characteristics that were 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 have qualified as derivative instruments. As such, the holders’ conversion feature was bifurcated and accounted for separately from the Convertible Senior Unsecured Notes. The holders’ conversion feature was 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 Predecessor 2016 Period and the year ended December 31, 2015. Subsequent to the Chapter 11 filings, the value of the debt holder conversion features was written off and is included in reorganization items in the accompanying consolidated statement of operations for the Predecessor 2016 Period. Mandatory Prepayment Feature - PGC Senior Secured Notes. As discussed further in Note 6 and Note 11 , the Senior Secured Notes contained a mandatory prepayment feature that was triggered if the outstanding principal amount of the unsecured 8.75% Senior Notes due 2020 exceeded $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 was identified as an embedded derivative as the feature (i) possessed economic characteristics that were 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 have qualified as derivative instruments. As such, the mandatory prepayment feature contained in the PGC Senior Secured Notes was bifurcated and accounted for separately from those notes. The mandatory prepayment feature contained in the PGC Senior Secured notes was recorded at fair value each reporting period with changes in fair value included in interest expense in the accompanying consolidated statements of operations for the Predecessor 2016 Period and the year ended December 31, 2015. Subsequent to the Chapter 11 filings, the value of the mandatory prepayment feature was written off and is included in reorganization items in the accompanying consolidated statement of operations for the Predecessor 2016 Period. Fair Value of Derivatives The following table presents the fair value of the Company’s derivative contracts on a gross basis without regard to same-counterparty netting (in thousands): Successor Predecessor December 31, December 31, Type of Contract Balance Sheet Classification 2016 2015 Derivative assets Oil price swaps Derivative contracts - current $ — $ 68,224 Oil collars—three way Derivative contracts - current — 17,300 Derivative liabilities Oil price swaps Derivative contracts - current (13,395 ) — Natural gas price swaps Derivative contracts - current (14,143 ) — Natural gas basis swaps Derivative contracts - current — (1,748 ) Debt holder conversion feature Current maturities of long-term debt — (29,355 ) Mandatory prepayment feature - PGC Senior Secured Notes Current maturities of long-term debt — (2,941 ) Oil price swaps Derivative contracts - noncurrent (2,105 ) — Natural gas price swaps Derivative contracts - noncurrent (71 ) — Total net derivative contracts $ (29,714 ) $ 51,480 See Note 6 for additional discussion of the fair value measurement of the Company’s derivative contracts and Note 11 for discussion of the debt holder conversion and mandatory prepayment features.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The following table presents the balance and activity of the asset retirement obligations (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Beginning balance $ 92,413 $ 103,578 $ 54,402 $ 424,117 Liability incurred upon acquiring and drilling wells 121 505 1,662 4,968 Revisions in estimated cash flows(1) 12,397 — 44,060 (5,848 ) Liability settled or disposed in current period(2) (540 ) (36,979 ) (1,023 ) (377,927 ) Accretion 2,090 4,365 4,477 9,092 Impact of fresh start accounting — 20,944 — — Ending balance 106,481 92,413 103,578 54,402 Less: current portion 66,154 65,678 8,399 — Asset retirement obligations, net of current $ 40,327 $ 26,735 $ 95,179 $ 54,402 ____________________ (1) Revisions for the Successor 2016 Period and the year ended December 31, 2015 relate primarily to changes in estimated well lives. (2) Liability settled or disposed for the Predecessor 2016 Period includes $34.1 million associated with the WTO Properties sold in January 2016. Liability settled or disposed for the year ended December 31, 2014, includes $366.0 million associated with the Gulf Properties sold in February 2014. For further discussion of the sale of properties see Note 5 .

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies 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, 2016 , 2015 and 2014. Employee termination benefits were $12.3 million for the Successor 2016 Period, with approximately $5.7 million accrued at December 31, 2016 for payment in the first quarter of 2017 and $18.4 million for the Predecessor 2016 Period, primarily as a result of reductions in workforce. 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. 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 in order to mitigate a portion of the effect of this price volatility on the Company’s cash flows. See Note 12 for the Company’s open oil and natural gas commodity derivative contracts. The Company historically has depended on cash flows from operating activities and, as necessary, borrowings under its senior credit facility to fund its capital expenditures. Based on its cash balances, cash flows from operating activities and net borrowing availability under the New First Lien Exit Facility, the Company expects to be able to fund its planned capital expenditures budget, debt service requirements and working capital needs for 2017; however, oil or natural gas prices decline from current levels, 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. The Company subsequently refinanced the New First Lien Exit Facility in February 2017. See Note 21 for additional discussion. Litigation and Claims Chapter 11 Proceedings The Plan in the Chapter 11 Cases discharged claims, including claims related to litigation proceedings against the Company that arose before such date. The Plan generally treated such claims as general unsecured claims that will receive only partial distribution of the amounts of consideration set aside for such claims under the Plan, which consists of cash, shares of New Common Stock and Warrants, once their amounts, if any, are finally determined by the Bankruptcy Court or otherwise. The effectiveness of the Plan also resulted in the release of certain claims held by the Company against various parties to the restructuring and related parties, including certain of the Company’s current and former officers and former directors. See Note 1 for further discussion about the Company’s Bankruptcy Petitions and the Chapter 11 Cases. To the extent that a claim related to a pre-petition proceeding or action is not characterized as a pre-petition general unsecured claim, the Company does not believe that such claim would be material, although the anticipated resolution of any such proceeding or action is inherently unpredictable. Successor Claims On October 14, 2016, Lisa West and Stormy Hopson filed a class action complaint in the United States District Court for the Western District of Oklahoma against SandRidge Exploration and Production, LLC, among other defendants. In their complaint, plaintiffs assert various tort claims seeking relief for damages allegedly incurred by the plaintiffs and the proposed class for injury to property and for the purchase of insurance policies allegedly needed by the plaintiffs and the proposed class for seismic activity allegedly caused by the defendants’ operation of wastewater disposal wells. An estimate of reasonably probable losses associated with this action cannot be made at this time. The Company had not established any reserves relating to this action. Predecessor Claims As previously disclosed, on February 4, 2015, the staff of the Securities and Exchange Commission (the “SEC”) Enforcement Division in Washington, D.C., notified the Company that it had commenced an informal inquiry concerning the Company’s accounting for, and disclosure of, its CO 2 delivery shortfall penalties under the terms of the Gas Treating and CO 2 Delivery Agreement, dated June 29, 2008, between SandRidge Exploration and Production, LLC, and Oxy USA Inc. Additionally, the Company received a letter from an attorney for a former employee at the Company (the “Former Employee”). In the letter, the attorney alleged, among other things, that the Former Employee had been terminated because he had objected to the levels of oil and gas reserves disclosed by the Company in its public filings. Over 85% of such reserves were calculated by an independent petroleum engineering firm. The Audit Committee of the Company’s pre-emergence Board of Directors retained an independent law firm to review the Former Employee’s allegations and the circumstances of the Former Employee’s termination. In addition, the Company reported the Former Employee’s allegations to the SEC staff, which thereafter issued two subpoenas to the Company relating to the Former Employee’s allegations. Counsel for the Audit Committee responded to both of these subpoenas. During the course of the above inquiries, the SEC issued a subpoena to the Company seeking documents relating to employment-related agreements between the Company and certain employees. The Company cooperated with this inquiry and, after discussion with the staff, the Company sent corrective letters to certain current and former employees who had entered into agreements containing language that may have been inconsistent with SEC rules prohibiting a company from impeding an individual from communicating directly with the SEC about possible securities law violations. The Company also updated its Code of Conduct and other relevant policies. On June 16, 2016, the SEC filed a proof of claim in the Company’s Chapter 11 Cases in the amount of $1.2 million as a result of the SEC staff’s inquiry concerning employment-related agreements. As a result of the SEC’s proof of claim, the Company established a $1.4 million reserve for this matter. On December 20, 2016, the Company and the SEC settled both the inquiry involving employment-related agreements and the inquiry involving the termination of the Former Employee. Pursuant to the settlement agreement, the Company agreed to pay a fine in the amount of $1.4 million . The fine will be treated as a general unsecured claim under the Plan and, as such, the Company expects to pay approximately $0.1 million to resolve these two inquiries. The Company neither admitted nor denied any violations as part of the settlement agreement. Additionally, the SEC informed the Company that as part of the settlement agreement, the SEC would not be recommending charges against the Company with regard to its pre-petition disclosures of the CO2 delivery shortfall penalties under the Company’s agreement with Oxy USA Inc., or with regard to the Company’s pre-petition processes and disclosures related to its reserves. In addition to the matters described above, the Company is involved in various lawsuits. claims and proceedings which are being handled and defended by the Company in the ordinary course of business.

Equity

Equity	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Equity	Equity Successor Equity New Common Stock. As discussed in Note 1 , on the Emergence Date, the Company issued an aggregate of approximately 18.9 million shares of its New Common Stock, par value $0.001 per share, to the holders of allowed claims, as defined in the Plan, and approximately 0.4 million shares of New Common Stock were reserved for future distributions under the Plan. Additionally, during the Successor 2016 Period, voluntary conversions of New Convertible Notes resulted in the issuance of New Company Stock. See Note 11 for further discussion of the New Convertible Notes. Warrants. A s discussed in Note 1 , on the Emergence Date, the Company issued approximately 4.9 million Series A Warrants, 4.5 million of which was issued immediately upon emergence and 2.1 million Series B Warrants, 1.9 million of which was issued immediately upon emergence, that were initially exercisable for one share of New Common Stock per Warrant at initial exercise prices of $41.34 and $42.03 per share, respectively, subject to adjustments pursuant to the terms of the Warrants, to certain holders of general unsecured claims as defined in the Plan. The Warrants are exercisable from the Emergence Date until October 4, 2022. The Warrants contain customary anti-dilution adjustments in the event of any stock split, reverse stock split, reclassification, stock dividend or other distributions. Unregistered Sales of Equity Securities. The Company relied on Section 1145(a)(1) of the Bankruptcy Code as an exemption from the registration requirements of the Securities Act for the issuance of the New Common Stock, the New Convertible Notes and the Warrants. Section 1145(a)(1) of the Bankruptcy Code exempts the offer and sale of securities under a plan of reorganization from registration under Section 5 of the Securities Act and state laws if three principal requirements are satisfied: • the securities must be issued under a plan of reorganization by the debtor, its successor under a plan, or an affiliate participating in a joint plan of reorganization with the debtor; • the recipients of the securities must hold a claim against, an interest in, or a claim for administrative expense in the case concerning the debtor or such affiliate; and • the securities must be issued either (a) in exchange for the recipient’s claim against, interest in or claim for administrative expense in the case concerning the debtor or such affiliate or (b) principally in such exchange and partly for cash or property. Treasury Stock. The Company makes required statutory tax payments on behalf of employees when their restricted stock awards vest and withhold a number of vested shares of common stock having a value on the date of vesting equal to the tax obligation. The number of shares withheld for taxes and the associated value of those shares for the Successor 2016 Period were insignificant. These shares were accounted for as treasury stock when withheld, and then immediately retired. Predecessor Equity Preferred Stock. As discussed in Note 1 , on the Emergence Date the Company’s authorized 7.0% and 8.5% convertible perpetual preferred stock was canceled and released under the Plan without receiving any recovery on account thereof. Each outstanding share of convertible perpetual preferred stock was 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 was entitled to an annual dividend payable semi-annually in cash, common stock or a combination thereof, at the Company’s election. The Company could 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 was not redeemable by the Company at any time. For the year ended December 31, 2015 , approximately 0.2 million shares were converted into approximately 3.0 million shares of the Predecessor Company’s common stock. The following table summarizes information about each series of the Predecessor 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. Prior to the Chapter 11 petition filings, dividends on the Company’s 8.5% and 7.0% convertible perpetual preferred stock could be paid in cash or with shares of the Company’s common stock at the Company’s election. In the first quarter of 2016, prior to the February semi-annual dividend payment date, the Company announced the suspension of the semi-annual dividend on its 8.5% convertible perpetual preferred stock. The Company suspended payment of the cumulative dividend on its 7.0% convertible perpetual preferred stock during the third quarter of 2015. The final dividend payment for the previously outstanding 6.0% convertible preferred stock was made during 2014, as it fully converted to common stock in 2014. The Company ceased accruing dividends on its 8.5% and 7.0% convertible perpetual preferred stock as of May 16, 2016, in conjunction with the Chapter 11 petition filings. Preferred stock dividend payments and accruals for the Company’s 8.5% , 7.0% and 6.0% convertible perpetual preferred stock are as follows (in thousands): Predecessor Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 8.5% Convertible perpetual preferred stock Dividends paid in cash $ — $ 11,262 $ 22,525 Dividends satisfied in shares of common stock(1) $ — $ 11,262 $ — Accrued dividends at period end $ — $ 8,447 $ 8,447 Dividends in arrears $ 11,262 $ — $ — 7.0% Convertible perpetual preferred stock Dividends paid in cash $ — $ — $ 21,000 Dividends satisfied in shares of common stock(2) $ — $ 10,500 $ — Accrued dividends at period end $ — $ 13,125 $ 2,625 Dividends in arrears $ 21,000 $ 10,500 $ — 6.0% Convertible perpetual preferred stock Dividends paid in cash $ — $ — $ 12,000 Accrued dividends at period end $ — $ — $ — ____________________ (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 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 consolidated statement of operations. 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 Predecessor 2016 Period and years ended December 31, 2015 and 2014 are presented in the accompanying consolidated statements of operations. See Note 19 for discussion of the Company’s (loss) earnings per share calculation. Common Stock. As discussed in Note 1 , on the Emergence Date the Company’s authorized common stock was canceled and released under the Plan without receiving any recovery on account thereof. 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 Company had 2.1 million shares of common stock held in treasury at December 31, 2015. 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 11 for additional discussion of the redemption of Senior Unsecured Notes. Conversions of Convertible Senior Unsecured Notes. During the Predecessor 2016 Period and year ended December 31, 2015, the Company issued approximately 84.4 million and 92.8 million shares, respectively, of common stock upon the exercise of conversion options by holders of approximately $232.1 million and $255.3 million in par value, respectively, 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 11 for additional discussion of the Convertible Senior Unsecured Notes transactions. See Note 16 for discussion of the Company’s share-based compensation. Treasury Stock. The following table shows the number of shares withheld for taxes and the associated value of those shares (in thousands). These shares were accounted for as treasury stock when withheld, and then immediately retired. Predecessor Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Number of shares withheld for taxes 1,122 1,872 1,034 Value of shares withheld for taxes $ 44 $ 2,428 $ 6,373 Prior to the Emergence Date, shares of Predecessor Company common stock held as assets in a trust for the Company’s non-qualified deferred compensation plan were accounted for as treasury shares. These shares were not included as outstanding shares of common stock for accounting purposes, and were canceled on the Emergence Date. No further matching contributions will be made to the non-qualified deferred compensation plan by the Successor Company. Stockholder Receivable. The Predecessor Company was 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. At December 31, 2015, the remaining $1.3 million receivable related to this settlement was classified as a component of additional paid-in capital in the accompanying consolidated balance sheet. In accordance with the Plan, the remaining balance of this receivable was fully discharged on the Emergence Date.

Share-Based Compensation

Share-Based Compensation	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-Based Compensation	Share-Based Compensation As discussed in Note 1 , the Predecessor Company’s common stock was canceled and New Common Stock was issued on the Emergence Date. Accordingly, the Predecessor Company's then existing share-based compensation awards were also canceled, which resulted in the recognition of any previously unamortized expense related to the canceled awards on the date of cancellation. Share based compensation for the Predecessor and Successor periods are not comparable. Successor Share-Based Compensation Omnibus Incentive Plan. Pursuant to terms of the Plan, the SandRidge Energy, Inc. 2016 Omnibus Incentive Plan (the “Omnibus Incentive Plan”) became effective on the Emergence Date. The Successor Company’s board of directors or any committee duly authorized thereby, will administer the Omnibus Incentive Plan. The committee has broad authority under the Omnibus Incentive Plan to, among other things: (i) select participants; (ii) determine the types of awards that participants are to receive and the number of shares that are to be subject to such awards; and (iii) establish the terms and conditions of awards, including the price (if any) to be paid for the shares or the award. Persons eligible to receive awards under the Omnibus Incentive Plan include non-employee directors, employees of the Successor Company or any of its affiliates, and certain consultants and advisors to the Successor Company or any of its affiliates. The types of awards that may be granted under the Omnibus Incentive Plan include stock options, restricted stock, performance awards and other forms of awards granted or denominated in shares of New Common Stock, as well as certain cash-based awards. The maximum number of shares of New Common Stock that may be issued or transferred pursuant to awards under the Omnibus Incentive Plan is approximately 4.6 million . If any stock option or other stock-based award granted under the Omnibus Incentive Plan expires, terminates or is canceled for any reason without having been exercised in full, the number of shares of New Common Stock underlying any unexercised award shall again be available for the purpose of awards under the Omnibus Incentive Plan. If any shares of restricted stock, performance awards or other stock-based awards denominated in shares of New Common Stock awarded under the Plan are forfeited for any reason, the number of forfeited shares shall again be available for purposes of awards under the Omnibus Incentive Plan. Any award under the Omnibus Incentive Plan settled in cash shall not be counted against the maximum share limitation. As is customary in incentive plans of this nature, each share limit and the number and kind of shares available under the Omnibus Incentive Plan and any outstanding awards, as well as the exercise or purchase prices of awards, and performance targets under certain types of performance-based awards, are subject to adjustment in the event of certain reorganizations, mergers, combinations, recapitalizations, stock splits, stock dividends or other similar events that change the number or kind of shares outstanding, and extraordinary dividends or distributions of property to the Company’s stockholders. Restricted Common Stock Awards. During October 2016, awards for approximately 1.4 million shares of restricted stock were granted under the Omnibus Incentive Plan. These restricted shares will vest over a three year period. The Successor Company recognized share-based compensation expense of $6.6 million , net of $0.3 million capitalized, for the Successor 2016 Period. Additionally, share-based compensation expense for the Successor 2016 Period includes $4.3 million for the accelerated vesting of 0.2 million restricted common stock awards related to the Successor Company’s reduction in workforce during the fourth quarter of 2016. The following table presents a summary of the Successor Company’s unvested restricted stock awards. Number of Shares Weighted- Average Grant Date Fair Value (In thousands) Unvested restricted shares outstanding at October 1, 2016 — $ — Granted 1,448 $ 24.32 Vested (14 ) $ 24.32 Forfeited / Canceled (27 ) $ 24.32 Unvested restricted shares outstanding at December 31, 2016 1,407 $ 24.32 As of December 31, 2016, the Successor Company’s unrecognized compensation cost related to unvested restricted stock awards was $27.1 million . The remaining weighted-average contractual period over which this compensation cost may be recognized is 2.8 years. The Successor Company’s restricted stock awards are equity-classified awards. Predecessor Share-Based Compensation Restricted Common Stock Awards. The Predecessor Company’s restricted common stock awards generally vested over a four -year period, subject to certain conditions, and were valued based upon the market value of the common stock on the date of grant. The following table presents a summary of the Predecessor Company’s unvested restricted stock awards. Number of Shares Weighted- Average Grant Date Fair Value (In thousands) 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 Granted — $ — Vested (3,034 ) $ 5.34 Forfeited / Canceled (2,592 ) $ 4.31 Predecessor ending unvested restricted shares at October 1, 2016 — $ — The Predecessor Company issued 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, (the “2009 Plan”). Total share-based compensation expense was measured using the grant date fair value for equity-classified awards and using the fair value at period end for liability-classified awards. The Predecessor Company recognized share-based compensation expense of $11.2 million , net of $1.7 million capitalized, for the Predecessor 2016 Period, and $21.7 million and $22.6 million , net of $5.9 million and $6.0 million capitalized for the years ended December 31, 2015 and 2014 , respectively. Share-based compensation expense for the Predecessor 2016 Period includes $5.4 million for the accelerated vesting of 1.3 million restricted common stock awards related to the Predecessor Company’s reduction in workforce during the first quarter of 2016. There was no significant activity related to the Predecessor Company’s outstanding unvested restricted stock units, performance units and performance share units during the Predecessor 2016 Period. In conjunction with the cancellation of the Predecessor Company’s common stock and termination of the 2009 Plan on the Emergence Date, the unrecognized compensation cost related to the Predecessor Company’s unvested restricted common stock awards of $5.9 million was expensed.

Incentive and Deferred Compensa

Incentive and Deferred Compensation Plans	12 Months Ended
	Dec. 31, 2016
Compensation Related Costs [Abstract]
Incentive and Deferred Compensation Plans	Incentive and Deferred Compensation Plans Performance Incentive Plan. In January 2016, the Company implemented a performance incentive plan. The plan replaced, on a prospective basis, the Company’s previous annual incentive plan, including long-term incentive awards, and provided for quarterly cash payments at a target percentage to participants based upon corporate performance goals with aggregate annual payout opportunity ranging from 0% to 200% . The first three quarterly cash payments were limited to no greater than target payouts with a cash make up payment for above target performance based on the Company’s annual performance results to be made in the first quarter of 2017. Under this plan, the Predecessor Company paid out approximately $17.8 million during the first two quarters of 2016 and the Successor Company paid out approximately $7.1 million during the fourth quarter of 2016, with approximately $15.8 million accrued at December 31, 2016 for payment in the first quarter of 2017. Annual Incentive Plan. Prior to January 2016, for certain members of management, the annual incentive plan incorporated 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 , the Company had accrued approximately $21.6 million 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, which was paid in the first quarter of 2016. Deferred Compensation Plans. The Company maintains a 401(k) retirement plan for its employees. Under this plan, eligible employees may elect to defer a portion of their earnings up to the maximum allowed by Internal Revenue Service (“IRS”) regulations. For the Successor 2016 Period, the Successor Company made matching cash contributions to the plan equal to 100% on the first 10% employee deferred wages for the period totaling $0.9 million . For the Predecessor 2016 Period, the Predecessor Company made matching cash contributions to the plan equal to 100% on the first 10% employee deferred wages for the period tot aling $4.9 million . For the years ended December 31, 2015 and 2014 , the Predecessor Company made matching contributions to the plan through cash purcha ses of Predecessor Company stock equal to 100% on the first 10% employee deferred wages. Retirement plan expense for the years ended December 31, 2015 and 2014 was approximately $7.9 million and $8.7 million , respectively. Participants in the plan are immediately 100% vested in the discretionary employee contributions and related earnings on those contributions. The Company's matching contributions and related earnings vest based on years of service, with full vesting occurring on the fourth anniversary of employment. The Company maintains a non-qualified deferred compensation plan that allowed eligible highly compensated employees to elect to defer income exceeding the IRS annual limitations on qualified 401(k) retirement plans through December 31, 2016. The Predecessor Company made insignificant matching contributions on non-qualified contributions for the Successor 2016 Period, the Predecessor 2016 Period and years ended December 31, 2015 and 2014. On December 31, 2016 , the Successor Company began the process of terminating the non-qualified deferred compensation plan. No employee or employer contributions will be made to the plan after December 31, 2016 and in accordance with the plan termination procedures, the remaining assets held in the plan, of approximately $7.5 million as of December 31, 2016, will be fully distributed to participating employees throughout 2017 and the first quarter of 2018. 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, 2016
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The Company’s income tax provision (benefit) consisted of the following components (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Current Federal $ — $ — $ — $ (1,160 ) State 9 11 123 (1,133 ) 9 11 123 (2,293 ) Deferred Federal — — — — State — — — — — — — — Total provision (benefit) 9 11 123 (2,293 ) Less: income tax provision attributable to noncontrolling interest — — 90 283 Total provision (benefit) attributable to SandRidge Energy, Inc. $ 9 $ 11 $ 33 $ (2,576 ) A reconciliation of the provision (benefit) for income taxes at the statutory federal tax rate to the Company’s actual income tax provision (benefit) is as follows (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Computed at federal statutory rate $ (116,891 ) $ 504,283 $ (1,512,325 ) $ 122,362 State taxes, net of federal benefit (3,696 ) 10,512 (19,988 ) 4,145 Non-deductible expenses 144 462 816 1,895 Non-deductible debt costs — 22,694 10,228 — Stock-based compensation 306 5,884 6,700 1,467 Net effects of consolidating the non-controlling interests’ tax provisions — — 218,196 (34,614 ) Discharge of debt and other reorganization related items — 359,278 — — Change in valuation allowance 120,144 (903,102 ) 1,296,405 (96,769 ) Other 2 — 1 (1,062 ) Total provision (benefit) attributable to SandRidge Energy, Inc. $ 9 $ 11 $ 33 $ (2,576 ) 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, 2016 , 2015 and 2014 the balance of the valuation allowance was $1.1 billion , $2.0 billion , and $649.6 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, 2016 . Thus, the Company’s effective tax rate and tax expense for the Successor 2016 Period and Predecessor 2016 Period continue to be low as a result of the Company not recognizing an income tax benefit associated with its net (loss) income from the same periods. Significant components of the Company’s deferred tax assets and liabilities are as follows (in thousands): Successor Predecessor December 31, 2016 December 31, 2015 Deferred tax liabilities Investments(1) $ 275,128 $ 138,310 Derivative contracts — 30,989 Long-term debt — 10,017 Total deferred tax liabilities 275,128 179,316 Deferred tax assets Property, plant and equipment 751,683 807,275 Derivative contracts 11,274 — Allowance for doubtful accounts 1,487 18,702 Net operating loss carryforwards 527,079 1,190,799 Compensation and benefits 14,494 18,607 Alternative minimum tax credits and other carryforwards 43,770 44,302 Asset retirement obligations 40,399 38,314 CO 2 under-delivery shortfall penalty — 40,654 Other 4,663 4,305 Total deferred tax assets 1,394,849 2,162,958 Valuation allowance (1,119,721 ) (1,983,642 ) Net deferred tax liability $ — $ — ____________________ (1) Includes the Company’s deferred tax liability resulting from its investment in the Royalty Trusts. 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. As discussed in Note 1 , on the Emergence Date the Company’s existing convertible perpetual preferred stock and the Company’s common stock were canceled and New Common Stock was issued resulting in the Company experiencing an ownership change under IRC Section 382. Further, certain of the transactions that occurred upon the Company’s emergence from bankruptcy on October 4, 2016 materially impacted the Company’s tax attributes. Cancellation of indebtedness income resulting from these transactions reduced the Company’s tax attributes, including but not limited to federal net operating loss carryforwards, in the amount of $3.7 billion . The Company analyzed alternatives available within the IRC to taxpayers in Chapter 11 bankruptcy proceedings in order to minimize the impact of the October 4, 2016 ownership change and cancellation of indebtedness income on its tax attributes. Upon filing its 2016 U.S. Federal income tax return, the Company plans to elect an available alternative that does not subject existing tax attributes to an IRC Section 382 limitation. However, should an additional ownership change become likely to occur prior to filing its 2016 U.S. Federal income tax return, the Company will evaluate the remaining available alternative which would likely result in the Company experiencing a limitation that subjects existing tax attributes at emergence to an IRC Section 382 limitation which could result in some or all of the remaining net operating loss carryforwards expiring unused. The ownership change did not result in a current federal tax liability at December 31, 2016 . As of December 31, 2016, the Company had approximately $9.3 million of alternative minimum tax credits available that do not expire. In addition, the Company had approximately $1.3 billion of federal net operating loss carryovers after attribute reduction resulting from cancellation of indebtedness that expire during the years 2028 through 2036 . At December 31, 2016 and 2015 , 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): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Unrecognized tax benefit at January 1 $ 81 $ 81 $ 77 Changes to unrecognized tax benefits related to a prior year 3 — 4 Unrecognized tax benefit at December 31 $ 84 $ 81 $ 81 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, 2016 , 2015 and 2014 . 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 2013 to present remain open for federal examination. Additionally, tax years 2005 through 2012 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, 2016
Earnings Per Share [Abstract]
(Loss) Earnings per Share	(Loss) Earnings per Share As discussed in Note 1 , on the Emergence Date, the Predecessor Company’s then-authorized common stock was canceled, the New Common Stock and Warrants were issued and the Omnibus Incentive Plan became effective. The following table summarizes the calculation of weighted average common shares outstanding used in the computation of diluted (loss) earnings per share: Net (Loss) Income Weighted Average Shares (Loss) Earnings Per Share (In thousands, except per share amounts) Period from October 2, 2016 to December 31, 2016 (Successor) Basic loss per share $ (333,982 ) 18,967 $ (17.61 ) Effect of dilutive securities Restricted stock(1) — — Warrants(1) — — New Convertible Notes(2) — — Diluted loss per share $ (333,982 ) 18,967 $ (17.61 ) Period from January 1, 2016 to October 1, 2016 (Predecessor) Basic earnings per share $ 1,424,476 708,928 $ 2.01 Effect of dilutive securities Restricted stock and units(3) — — Diluted earnings per share $ 1,424,476 708,928 $ 2.01 Year Ended December 31, 2015 (Predecessor) Basic loss per share $ (3,735,495 ) 521,936 $ (7.16 ) Effect of dilutive securities Restricted stock and units(3) — — Convertible preferred stock(4) — — Convertible senior unsecured notes(5) — — Diluted loss per share $ (3,735,495 ) 521,936 $ (7.16 ) Year Ended December 31, 2014 (Predecessor) Basic earnings per share $ 203,260 479,644 $ 0.42 Effect of dilutive securities Restricted stock — 2,181 Convertible preferred stock(4) 6,500 17,918 Diluted earnings per share $ 209,760 499,743 $ 0.42 ____________________ (1) No incremental shares of potentially dilutive restricted stock awards or warrants were included for the Successor 2016 Period as their effect was antidilutive. (2) Potential common shares related to the New Convertible Notes covering 14.6 million shares for the Successor 2016 Period were excluded from the computation of loss per share because their effect would have been antidilutive under the if-converted method. (3) No incremental shares of potentially dilutive restricted stock awards or units were included for the Predecessor 2016 Period and the year ended December 31, 2015 as their effect was antidilutive under the treasury stock method. (4) Potential common shares related to the Predecessor Company’s then-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. (5) Potential common shares related to the Predecessor Company’s then-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. See Note 15 for discussion of the Predecessor Company’s convertible perpetual preferred stock. The remaining outstanding New Convertible Notes were converted into shares of New Common Stock as a result of the Company’s entry into the refinanced credit facility on February 10, 2017. For further discussion see Note 21 .

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2016
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. 2014 Divestiture. See Note 5 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 owned a significant number of shares of the Predecessor Company’s common stock at the time the transaction occurred.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2016
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Acquisition of Properties. On February 10, 2017, the Company acquired approximately 13,000 net acres in Woodward County, Oklahoma for approximately $47.8 million in cash. Also included in the acquisition were working interests in 4 wells previously drilled on the acreage. Refinancing of New First Lien Exit Facility. On February 10, 2017, the New First Lien Exit Facility was refinanced into a new $600.0 million credit facility with a $425.0 million borrowing base. The amended credit facility agreement had the following impacts: • increased the principal amount of commitments to $600.0 million from $425.0 million ; • extended the maturity date to March 31, 2020 from February 4, 2020; • borrowing base determinations now include the Company’s proportionately consolidated share of proved reserves held by the Royalty Trusts; • reduced the interest rate from a flat base rate of LIBOR plus 4.75% per annum to a pricing grid tied to borrowing base utilization of (A) LIBOR plus an applicable margin that varies from 3.00% to 4.00% per annum, or (B) the base rate plus an applicable margin that varies from 2.00% to 3.00% per annum; • reduced the LIBOR floor from 1% to 0% ; • eliminated the minimum proved developing producing reserves asset coverage ratio; • removed the requirement to maintain $50.0 million in a cash collateral account controlled by the administrative agent; • eliminated the holiday from borrowing base determinations and the maximum consolidated total net leverage ratio and the minimum consolidated interest coverage ratio covenants; and • eliminated certain negative covenants, such as the $20.0 million liquidity requirement and the limitation on capital expenditures. Conversions of New Convertible Notes to New Common Stock. During the period from January 1, 2017 to February 9, 2017, holders of approximately $5.1 million in aggregate principal amount of the New Convertible Notes exercised conversion options applicable to those notes, resulting in the issuance of approximately 0.3 million shares of New Common Stock. In conjunction with the refinancing of the New First Lien Exit Facility that took place on February 10, 2017, the remaining $263.7 million par value of the New Convertible Notes mandatorily converted into approximately 14.1 million shares of New Common Stock.

Supplemental Information on Oil

Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited)	12 Months Ended
	Dec. 31, 2016
Extractive Industries [Abstract]
Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited)	Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited) 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): Successor Predecessor December 31, December 31, 2016 2015 2014 Oil and natural gas properties Proved $ 840,201 $ 12,529,681 $ 11,707,147 Unproved 74,937 363,149 290,596 Total oil and natural gas properties 915,138 12,892,830 11,997,743 Less accumulated depreciation, depletion and impairment (353,030 ) (11,149,888 ) (6,359,149 ) Net oil and natural gas properties capitalized costs $ 562,108 $ 1,742,942 $ 5,638,594 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): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Acquisitions of properties Proved $ 5,142 $ 3,897 $ 35,376 $ 73,370 Unproved 5,491 1,899 210,065 123,649 Exploration(1) — 1,234 29,297 41,070 Development 27,429 149,924 571,562 1,288,395 Total cost incurred $ 38,062 $ 156,954 $ 846,300 $ 1,526,484 ____________________ (1) Includes seismic costs of $7.1 million and $10.8 million for the years ended December 31, 2015 and 2014 , respectively. Results of Operations for Oil and Natural Gas Producing Activities The Company’s results of operations from oil and natural gas producing activities are shown in the following table (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Revenues $ 98,307 $ 279,971 $ 707,434 $ 1,420,879 Expenses Production costs 27,640 135,715 324,141 377,819 Depreciation and depletion 33,971 86,613 319,913 434,295 Accretion of asset retirement obligations 2,090 4,365 4,477 9,092 Impairment 319,087 657,392 4,473,787 164,779 Total expenses 382,788 884,085 5,122,318 985,985 (Loss) income before income taxes (284,481 ) (604,114 ) (4,414,884 ) 434,894 Income tax expense (benefit)(1) 8 (5 ) 126 (2,852 ) Results of operations for oil and natural gas producing activities (excluding corporate overhead and interest costs) $ (284,489 ) $ (604,109 ) $ (4,415,010 ) $ 437,746 ____________________ (1) Reflects the Company’s effective tax rate for each period. Oil, Natural Gas and NGL Reserve Quantities 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 oil, natural gas and NGL 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 2016 , 2015 and 2014 . 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 Ryder Scott prepared the estimates of proved reserves for a majority of the Company’s properties as of December 31, 2016 . The remaining 6.0% 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. 2016 Activity. During 2016, on a pro forma combined basis, Predecessor Company and Successor Company recognized total downward revisions of prior estimates of approximately 105.4 MMBoe, predominantly from revisions of approximately 94.7 MMBoe due to well performance and 12.1 MMBoe due to a decrease in commodity prices. The negative revisions from well performance were from the Mid-Continent area and resulted from steeper than anticipated well production decline rates for Mississippian horizontal wells in areas with increased natural fracture density and that have been developed with three or more horizontal wells per section as inter-well pressure communication has had more impact on well performance than originally forecasted. Additionally, changing pressure conditions in the Company’s Mississippian wells producing with artificial lift have resulted in increased production decline rates that are now becoming more predictable on a large group of base wells as this population of wells has been producing for more than two years. Of the total performance revisions, approximately 85% were to gas and associated NGL reserves, with the revisions to gas mostly from changes made to late-life decline rates, and 15% were to oil reserves. Other decreases of reserves excluding production included the sale of WTO reserves of 24.6 MMBoe and 19.1 MMBoe of adjustment from change in accounting for Trusts. These decreases were partially offset by approximately 7.8 MMBoe of extensions due to successful drilling. 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. The summary below presents changes in the Company’s estimated reserves. Oil NGL Natural Gas (MBbls) (MBbls) (MMcf)(1) Proved developed and undeveloped reserves As of December 31, 2013 - Predecessor 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) - Predecessor 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) - Predecessor 77,911 61,075 1,113,840 Adoption of ASU 2015-02 (6,971 ) (3,695 ) (50,508 ) Revisions of previous estimates (39,973 ) (21,475 ) (415,568 ) Extensions and discoveries 987 472 7,955 Sales of reserves in place (387 ) — (145,267 ) Production (4,315 ) (3,358 ) (44,124 ) As of October 1, 2016 - Predecessor 27,252 33,019 466,328 Revisions of previous estimates 23,978 1,139 915 Extensions and discoveries 2,868 448 10,309 Production (1,214 ) (999 ) (12,770 ) As of December 31, 2016 - Successor 52,884 33,607 464,782 Proved developed reserves As of December 31, 2013 - Predecessor 83,893 35,807 951,609 As of December 31, 2014 - Predecessor 79,022 56,823 1,203,447 As of December 31, 2015 - Predecessor 48,639 51,089 964,617 As of October 1, 2016 - Predecessor 24,541 30,238 428,050 As of December 31, 2016 - Successor 25,911 29,290 393,028 Proved undeveloped reserves As of December 31, 2013 - Predecessor 58,748 23,245 438,820 As of December 31, 2014 - Predecessor 47,009 34,963 584,786 As of December 31, 2015 - Predecessor 29,272 9,986 149,223 As of October 1, 2016 - Predecessor 2,711 2,781 38,278 As of December 31, 2016 - Successor 26,973 4,317 71,754 ____________________ (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 as shown in the table below: Predecessor December 31, 2015 2014 Oil (MBbl) 7,004 11,027 NGL (MBbl) 3,694 4,761 Natural gas (MMcf) 50,508 70,833 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 ASC 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, 2016 , 2015 and 2014 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: Successor Predecessor December 31, December 31, 2016 2015 2014 Oil (per barrel) $ 38.59 $ 45.29 $ 91.65 NGL (per barrel) $ 10.99 $ 12.68 $ 32.79 Natural gas (per Mcf) $ 1.56 $ 1.87 $ 3.61 • 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). Successor Predecessor December 31, December 31, 2016 2015 2014 Future cash inflows from production $ 3,136,762 $ 6,387,944 $ 21,022,320 Future production costs (1,454,798 ) (2,731,542 ) (6,499,366 ) Future development costs(1) (665,516 ) (838,945 ) (1,810,201 ) Future income tax expenses (142 ) (901 ) (3,223,740 ) Undiscounted future net cash flows 1,016,306 2,816,556 9,489,013 10% annual discount (577,942 ) (1,501,994 ) (5,401,261 ) Standardized measure of discounted future net cash flows(2) $ 438,364 $ 1,314,562 $ 4,087,752 ____________________ (1) Includes abandonment costs. (2) Includes approximately $224.6 million and $643.3 million attributable to noncontrolling interests at December 31, 2015 and 2014 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): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Beginning present value $ 392,604 $ 1,314,562 $ 4,087,752 $ 4,017,611 Changes during the year Adoption of ASU 2015-02 — (224,965 ) — — Revenues less production and other costs (70,668 ) (144,256 ) (383,293 ) (1,043,060 ) Net changes in prices, production and other costs 35,684 (394,173 ) (3,813,465 ) 331,694 Development costs incurred 7,941 69,080 217,596 364,262 Net changes in future development costs (291,232 ) 436,041 273,437 (341,183 ) Extensions and discoveries 14,986 12,449 230,055 1,785,963 Revisions of previous quantity estimates 308,374 (728,254 ) (1,354,778 ) (77,688 ) Accretion of discount 9,375 91,337 512,483 477,458 Net change in income taxes — 402 1,426,333 (256,371 ) Purchases of reserves in-place — — 18,429 50,958 Sales of reserves in-place — (13,314 ) — (1,058,330 ) Timing differences and other(1) 31,300 (26,305 ) 100,013 (163,562 ) Net change for the year 45,760 (921,958 ) (2,773,190 ) 70,141 Ending present value(2) $ 438,364 $ 392,604 $ 1,314,562 $ 4,087,752 ____________________ (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 and $643.3 million attributable to noncontrolling interests at December 31, 2015 , and 2014 respectively.

Quarterly Financial Results (Un

Quarterly Financial Results (Unaudited)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Results (Unaudited)	Quarterly Financial Results (Unaudited) The Company’s operating results for each quarter of 2016 and 2015 are summarized below (in thousands, except per share data). Predecessor Successor First Quarter Second Quarter Third Quarter Fourth Quarter Fourth Quarter 2016 Total revenues $ 90,332 $ 99,421 $ 104,056 $ — $ 98,456 Loss from operations(1)(2) $ (273,555 ) $ (275,310 ) $ (357,338 ) $ — $ (336,345 ) Net (loss) income(1)(2)(3) $ (313,226 ) $ (515,911 ) $ (404,337 ) $ 2,674,271 (333,982 ) (Loss applicable) income available to SandRidge Energy, Inc. common stockholders(1)(2)(3) $ (324,107 ) $ (521,351 ) $ (404,337 ) $ 2,674,271 $ (333,982 ) (Loss applicable) income available per share to SandRidge Energy, Inc. common stockholders Basic $ (0.47 ) $ (0.73 ) $ (0.56 ) $ 3.72 $ (17.61 ) Diluted $ (0.47 ) $ (0.73 ) $ (0.56 ) $ 3.72 $ (17.61 ) Predecessor First Quarter Second Quarter Third Quarter Fourth Quarter 2015 Total revenues $ 215,308 $ 229,607 $ 180,152 $ 143,642 Loss from operations(4)(5) $ (1,088,456 ) $ (1,535,083 ) $ (1,059,733 ) $ (959,406 ) Net loss(4)(5) $ (1,151,874 ) $ (1,588,731 ) $ (796,485 ) $ (783,961 ) Loss applicable to SandRidge Energy, Inc. common stockholders(4)(5) $ (1,045,834 ) $ (1,375,556 ) $ (649,526 ) $ (664,579 ) Loss applicable per share to SandRidge Energy, Inc. common stockholders(6) Basic $ (2.19 ) $ (2.78 ) $ (1.23 ) $ (1.13 ) Diluted $ (2.19 ) $ (2.78 ) $ (1.23 ) $ (1.13 ) ____________________ (1) Includes impairment of $110.1 million , $253.6 million , $354.5 million and $319.1 million for the first, second, and third quarters and Successor 2016 Period, respectively. See Note 9 for further discussion of impairment. (2) Includes loss on settlement of contract of $89.1 million and gain on extinguishment of $41.3 million for the first quarter. (3) Includes (loss) gain on reorganization items related to the Company’s restructuring under Chapter 11 filings of $(200.9) million , $(42.8) million , and $2.7 billion for the second and third quarters and Predecessor fourth quarter, respectively. See Note 2 for further discussion of reorganization items. (4) 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 9 for further discussion of impairment. (5) 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. (6) Loss applicable 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 per share to common stockholders for each of the four quarters may not equal the fiscal year amount.

Summary of Significant Accoun30

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Business	Nature of Business. SandRidge Energy, Inc. is an oil and natural gas company with a principal focus on exploration and production activities in the Mid-Continent and Rockies regions of the United States. The Company’s Rockies properties were acquired during the fourth quarter of 2015. Additionally, the Company owned interests in the Gulf of Mexico and Gulf Coast until February 2014, as discussed in Note 5 .
Principles of Consolidation	Principles of Consolidation. The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern, which contemplates continuity of operations, realization of assets and satisfaction of liabilities in the normal course of business. The consolidated financial statements include the accounts of the Company and its wholly owned or majority owned subsidiaries. During the years ended December 31, 2015, and 2014, the Company fully consolidated the activities of each the SandRidge Mississippian Trust I (the “Mississippian Trust I”), SandRidge Mississippian Trust II (the “Mississippian Trust II”) and SandRidge Permian Trust (the “Permian Trust”) (each individually, a “Royalty Trust” and collectively, the “Royalty Trusts”) as variable interest entities (“VIEs”) for which the Company was the primary beneficiary. Activities of the Royalty Trusts attributable to third party ownership were presented as noncontrolling interest and included as a component of equity in the condensed consolidated balance sheet as of December 31, 2015 . As discussed further below, during the year ended December 31, 2016 , the Company proportionately consolidated the activities of the Royalty Trusts. All significant intercompany accounts and transactions have been eliminated in consolidation.
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 natural gas liquids (“NGL”) reserves; 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.
Restricted Cash	Restricted Cash. The Company maintains restricted escrow funds as required by certain contractual arrangements in accordance with the Plan.
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, which have a contractual maturity of one year or less. 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. As part of fresh start accounting, the allowance for doubtful accounts was reset to zero on the Emergence Date. Refer to Note 7 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 6 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. Fair value measurements for the electrical asset were based on replacement cost. Inputs used in the cost approach are based on the cost to a market participant buyer to acquire or construct a substitute asset of comparable utility, adjusted for inutility. 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 6 .
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. 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 12 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 during the Successor 2016 Period of $4.0 million and the Predecessor Company capitalized internal costs of $22.7 million , $45.1 million and $55.4 million to the full cost pool during the Predecessor 2016 Period and the years ended December 31, 2015 and 2014 , 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, electrical infrastructure, 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 2 to 30 years for equipment. When property and equipment components are disposed, the cost and the related accumulated depreciation are removed and any resulting gain or loss is reflected in the consolidated statements of operations. As part of fresh start accounting, property, plant and equipment were adjusted to their estimated fair value and depreciable lives were revised as of October 1, 2016, as described in Note 2 . 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. Impairment is measured as the excess of the carrying amount of the impaired asset or asset group over its fair value. See Note 9 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 includes unamortized line-of-credit debt issuance costs, if any, related to its credit facility in other assets in the consolidated balance sheets. Other debt issuance costs related to long-term debt, if any, are presented in the balance sheets as a direct deduction from the associated debt liability. Debt issuance costs are amortized to interest expense over the scheduled maturity period of the related debt. 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 relate primarily to the Company’s non-qualified deferred compensation plan, and have been designated as available for sale and measured at fair value using quoted prices readily available in the market pursuant to the fair value option which requires unrealized gains and losses be reported in earnings. Investments are included in other current assets and other assets in the accompanying consolidated balance sheets.
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 13 for further discussion of the Company’s asset retirement obligations. As part of fresh start accounting, the ARO liabilities were adjusted to their estimated fair value as described in Note 2 .
Revenue Recognition	For the years ended December 31, 2015 and 2014, the Company recognized revenues and expenses generated from daywork and footage drilling contracts as the services were performed since the Company did not bear the risk of completion of the well. The Company received 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 were recognized at the time mobilization services were performed. Revenues and expenses related to drilling and services are included in other revenue and expense in the accompanying consolidated statements of operations for the years ended December 31, 2015 and 2014. In general, natural gas purchased and sold by the midstream business was priced at a published daily or monthly index price. Sales to wholesale customers typically incorporated a premium for managing their transmission and balancing requirements. Midstream services revenues were recognized upon delivery of natural gas to customers and/or when services were rendered, pricing was determined and collectability was reasonably assured. Revenues from third-party midstream services were presented on a gross basis, since the Company acted as a principal by taking ownership of the natural gas purchased and taking responsibility of fulfillment for natural gas volumes sold. Revenues and expenses related to midstream and marketing are included in other revenue and expense in the accompanying consolidated statements of operations for the years ended December 31, 2015 and 2014. 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. Additionally, the Successor Company has made an accounting policy election to deduct transportation costs from oil, natural gas and NGL revenues. This resulted in presenting $7.4 million of transportation costs as a reduction from revenues in the Successor 2016 Period versus the presentation of $26.2 million , $45.3 million and $35.6 million of these costs as production expenses in the Predecessor 2016 Period, and the years ended December 31, 2015 and 2014, respectively. and 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 $1.7 million and $1.5 million at December 31, 2016 and 2015 , respectively. The Company includes the gas imbalance positions in other long-term obligations in the consolidated balance sheets.
Share-based Compensation	Allocation of Share-Based Compensation. For both the Successor and Predecessor Companies, equity compensation provided to employees directly involved in exploration and development activities is capitalized to the Company’s oil and natural gas properties. Equity compensation not capitalized is recognized in general and administrative expenses, production expenses, and other operating expense in the accompanying consolidated statements of operations.
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 Successor Company consist of unvested restricted stock awards and warrants, using the treasury method, and convertible senior notes, using the if-converted method. Potentially dilutive securities for the Predecessor Company 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 or the proceeds that would be received if the warrants were exercised are assumed to be used to repurchase shares at the average market price. Under the if-converted method, the Successor Company assumes the conversion of the New Convertible Notes to common stock and determines if it is more dilutive than including the expense associated with the New Convertible Notes in the computation of income available to common stockholders. Under the if-converted method, the Predecessor Company assumed the conversion of the preferred stock or Convertible Senior Unsecured Notes to common stock and determined if it was more dilutive than including the preferred stock dividends or expense associated with the Convertible Senior Unsecured 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 19 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 14 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 New First Lien Exit Facility constitutes a default under its commodity derivative contracts with counterparties that are lenders under the New First Lien Exit 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 for like commodities and derivative instruments 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 First Lien Exit Facility can be offset against amounts owed, if any, to such counterparty under the Company’s First Lien Exit 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. 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. The Company had sales exceeding 10% of total revenues to the following oil and natural gas purchasers (in thousands): Sales % of Revenue Period from October 2, 2016 through December 31, 2016 - Successor Targa Pipeline Mid-Continent West OK LLC $ 35,845 36.4 % Plains Marketing, L.P. $ 32,022 32.5 % Period from January 1, 2016 through October 1, 2016 - Predecessor Plains Marketing, L.P. $ 110,370 37.6 % Targa Pipeline Mid-Continent West OK LLC $ 108,238 36.8 % December 31, 2015 - Predecessor Plains Marketing, L.P. $ 318,018 41.4 % Targa Pipeline Mid-Continent West OK LLC $ 231,649 30.1 % December 31, 2014 - Predecessor Plains Marketing, L.P. $ 597,117 38.3 % Targa Pipeline Mid-Continent West OK LLC $ 333,027 21.4 %
Recent Accounting Pronouncements	Recent Accounting Pronouncements. The Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”) 2015-02, “Amendments to the Consolidation Analysis,” which 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 were effective for annual reporting periods beginning January 1, 2016 for the Company, including interim periods within that reporting period, with early adoption permitted. The Company adopted this guidance on January 1, 2016, which resulted in the determination that the Royalty Trusts no longer qualify as VIEs. As a result, the Successor and Predecessor Companies proportionately consolidated the activities of the Royalty Trusts in 2016. Under the proportionate consolidation method, the Company accounts for only its share of each Royalty Trust’s asset, liabilities, revenues and expenses within the appropriate classifications in the accompanying consolidated financial statements. The Company adopted the provisions of ASU 2015-02 on a modified retrospective approach by recording a cumulative-effect adjustment as of January 1, 2016 that resulted in decreases of approximately $243.4 million to total assets and approximately $510.2 million to noncontrolling interest and increases of approximately $9.7 million to accounts payable and approximately $257.1 million to retained earnings. These adjustments had no impact on prior period balances. The FASB issued ASU 2015-03, "Interest-Imputation of Interest (Topic 835): Simplifying the Presentation of Debt Issuance Costs," which requires debt issuance costs related to a recognized debt liability to be presented on the balance sheet as a direct deduction from the carrying amount of that debt liability rather than as an asset. The guidance was adopted on January 1, 2016, and resulted in a decrease of approximately $69.1 million to other assets and current maturities of long-term debt in the accompanying consolidated balance sheet for the year ended December 31, 2015, with no impact to the accompanying consolidated statements of operations. See Note 11 for treatment and classification of unamortized debt issuance costs subsequent to filing the Chapter 11 petitions. In August 2015, the FASB issued ASU 2015-15, “Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements,” which excludes line-of-credit debt issuance costs from the scope of ASU 2015-03. The guidance was adopted on January 1, 2016 in conjunction with the adoption of ASU 2015-03. The Company made an accounting policy election to present line-of-credit arrangement debt issuance costs as an asset and subsequently amortize the deferred debt issuance costs ratably over the term of the line-of-credit arrangement. The adoption of this ASU resulted in no impact to the consolidated financial statements. The FASB issued ASU 2014-15, “Presentation of Financial Statements - Going Concern (Subtopic 205-40): 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 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 Company adopted the provisions of this ASU for the year ended December 31, 2016 on a prospective basis. The adoption of this ASU had no impact to the Company’s disclosures included in this report. The FASB issued ASU 2016-06, “Derivatives and Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments” which eliminates diversity in practice in assessing embedded contingent call (put) options in debt instruments. The ASU requires adoption by application of a modified retrospective approach to existing and future debt instruments. The ASU is effective for the Company beginning January 1, 2017, with early adoption permitted. The Company early adopted the provisions of this ASU on the Emergence Date. The adoption of this ASU resulted in no impact to the consolidated financial statements and related disclosures. The FASB issued ASU 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Share-Based Payment Accounting” which was part of the FASB simplification initiative and involves several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The guidance requires adoption by various application methods, effective for the Company beginning January 1, 2017. The Company early adopted all provisions of this ASU on the Emergence Date. Upon adoption, the Company made an accounting policy election to account for forfeitures as they occur. The adoption of this ASU resulted in no impact to the consolidated financial statements and related disclosures. The FASB issued ASU 2016-18, “Statement of Cash Flows (Topic 230): Restricted Cash” to require inclusion of amounts generally described as restricted cash or restricted cash equivalents when reconciling the beginning of period and end of period total amounts shown on the statement of cash flows. This ASU is effective for the Company beginning January 1, 2018. The Company early adopted the provisions of this ASU on December 31, 2016, using a retrospective transition method for each period presented. As a result of the adoption, the Company included $52.8 million of restricted cash in the beginning of period and end of period total amounts shown on the Successor statement of cash flows for October 2, 2016 and December 31, 2016, respectively. There was no impact to the Predecessor statement of cash flows. Recent Accounting Pronouncements Not Yet Adopted. The FASB issued ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” which provides guidance concerning the recognition and measurement of revenue from contracts with customers. Its objective is to increase the usefulness of information in the financial statements regarding the nature, timing and uncertainty of revenues. 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 January 1, 2018 for the Company, with early adoption permitted in 2017. The ASU must be adopted using either the retrospective transition method, which requires restating previously reported results or the cumulative effect (modified retrospective) transition method, which utilizes a cumulative-effect adjustment to retained earnings in the period of adoption to account for prior period effects rather than restating previously reported results. The Company does not plan to early adopt and is currently evaluating the effect that the updated standard will have on its consolidated financial statements and related disclosures. 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 the Company on January 1, 2019. Early adoption is permitted. The Company does not plan to early adopt and is currently evaluating the effect that the guidance will have on its consolidated financial statements and related disclosures. The FASB issued ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments” with the objective of reducing the existing diversity in practice of classification on certain cash receipts and payments in the statement of cash flows. The guidance requires adoption by application of a retrospective method to each period presented. The amendments are effective for the Company on January 1, 2018, with early adoption permitted. The Company is currently evaluating the effect that the guidance will have on its consolidated financial statements. The FASB issued ASU 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other than Inventory” which removes the prohibition in ASC 740 against the immediate recognition of current and deferred income tax effects of intra-entity transfers of assets other than inventory. The amendments in this ASU are effective for the Company on January 1, 2018, with early adoption permitted on January 1, 2017. The ASU should be applied on a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption. The Company does not plan to early adopt and is currently evaluating the effect that the guidance will have on its consolidated financial statements. The FASB Issued ASU 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business,” which provides more consistency in applying the guidance, reduces the costs of application, and makes the definition of a business more operable. The ASU is effective for the Company on January 1, 2018 and amendments should be applied prospectively on and after January 1, 2018. Due to the prospective nature of the ASU, the Company cannot evaluate the impact to its consolidated financial statements until after adoption, and no disclosures are required upon transition.
Fair Value Transfers	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.

Fresh Start Accounting (Tables)

Fresh Start Accounting (Tables)	12 Months Ended
	Dec. 31, 2016
Reorganizations [Abstract]
Reconciliation of Enterprise Value to Fair Value	The following table reconciles the enterprise value to the estimated fair value of the Successor Company's common stock as of the Emergence Date (in thousands, except per share amounts): Enterprise value $ 1,089,808 Plus: Cash and cash equivalents 563,372 Less: Fair value of New Building Note (36,610 ) Less: Asset retirement obligation (92,412 ) Less: Fair value of New First Lien Exit Facility (414,954 ) Less: Fair value of New Convertible Notes (445,660 ) Less: Fair value of warrants, including warrants held in reserve for settlement of general unsecured claims (95,794 ) Fair value of Successor common stock issued upon emergence $ 567,750 Shares issued upon emergence on October 4, 2016, including shares held in reserve for settlement of general unsecured claims 19,371 Per share value $ 29.31
Reconciliation Of Enterprise Value To Estimated Reorganization Value	The following table reconciles the enterprise value to the estimated reorganization value as of the Emergence Date (in thousands): Enterprise value $ 1,089,808 Plus: cash and cash equivalents 563,372 Plus: other working capital liabilities 131,766 Plus: other long-term liabilities 8,549 Reorganization value of Successor assets $ 1,793,495
Schedule of Fresh-Start Adjustments	The following table reflects the reorganization and application of Accounting Standards Codification (“ASC”) 852 “Reorganizations” on the consolidated balance sheet as of October 1, 2016 (in thousands): Predecessor Company Reorganization Adjustments Fresh Start Adjustments Successor Company ASSETS Current assets Cash and cash equivalents $ 652,680 $ (142,148 ) (1) $ — $ 510,532 Restricted cash - collateral — 50,000 (2) — 50,000 Restricted cash - other — 2,840 (2) — 2,840 Accounts receivable, net 61,446 12,356 (3) — 73,802 Derivative contracts 10,192 — (669 ) (12) 9,523 Prepaid expenses 12,514 (8,218 ) (4) — 4,296 Other current assets 1,003 — 3,217 (13) 4,220 Total current assets 737,835 (85,170 ) 2,548 655,213 Oil and natural gas properties, using full cost method of accounting Proved 12,093,492 — (11,344,684 ) (14) 748,808 Unproved 322,580 — (205,578 ) (14) 117,002 Less: accumulated depreciation, depletion and impairment (11,637,538 ) — 11,637,538 (14) — 778,534 — 87,276 865,810 Other property, plant and equipment, net 357,528 (41 ) (93,782 ) (15) 263,705 Derivative contracts 70 — (70 ) (12) — Other assets 12,537 (3,770 ) (5) — 8,767 Total assets $ 1,886,504 $ (88,981 ) $ (4,028 ) $ 1,793,495 Predecessor Company Reorganization Adjustments Fresh Start Adjustments Successor Company LIABILITIES AND STOCKHOLDERS’ (DEFICIT) EQUITY Current liabilities Accounts payable and accrued expenses $ 140,448 $ (14,820 ) (6) $ — $ 125,628 Derivative contracts 2,982 — 1,666 (12) 4,648 Asset retirement obligations 8,573 — 57,105 (16) 65,678 Total current liabilities 152,003 (14,820 ) 58,771 195,954 Long-term debt — 731,735 (7) 1,610 (17) 733,345 Derivative contracts 935 — 304 (12) 1,239 Asset retirement obligations 62,896 — (36,161 ) (16) 26,735 Other long-term obligations 3 8,798 (8) (3 ) 8,798 Liabilities subject to compromise 4,346,188 (4,346,188 ) (9) — — Total liabilities 4,562,025 (3,620,475 ) 24,521 966,071 Equity SandRidge Energy, Inc. stockholders’ equity (deficit) Predecessor preferred stock 6 — (6 ) (18) — Predecessor common stock 718 — (718 ) (18) — Predecessor additional paid-in capital 5,315,655 — (5,315,655 ) (18) — Predecessor additional paid-in capital—stockholder receivable (1,250 ) 1,250 (10) — — Predecessor treasury stock, at cost (5,218 ) — 5,218 (18) — Successor common stock — 19 (11) — 19 Successor warrants — 88,382 (11) — 88,382 Successor additional paid-in capital — 739,023 (11) — 739,023 Accumulated deficit (7,985,411 ) 2,702,820 (9) 5,282,591 (19) — Total SandRidge Energy, Inc. stockholders’ (deficit) equity (2,675,500 ) 3,531,494 (28,570 ) 827,424 Noncontrolling interest (21 ) — 21 (20) — Total stockholders’ (deficit) equity (2,675,521 ) 3,531,494 (28,549 ) 827,424 Total liabilities and stockholders’ equity (deficit) $ 1,886,504 $ (88,981 ) $ (4,028 ) $ 1,793,495 Reorganization Adjustments 1. Reflects the net cash payments made upon emergence (in thousands): Sources: Proceeds from New Building Note $ 26,847 Total sources $ 26,847 Uses and transfers: Cash transferred to restricted accounts (collateral and general unsecured claims) $ 52,840 Payments and funding of escrow account related to professional fees 43,770 Payment on Senior Credit facility (principal and interest) 35,238 Repayment of Senior Secured Notes and Unsecured Notes 33,874 Payment of certain contract cures and other 3,273 Total uses and transfers 168,995 Net uses and transfers $ (142,148 ) 2. Funding of $50.0 million Cash Collateral account and the funding of $2.8 million to be held in reserve by the Company for distribution to satisfy allowed general unsecured claims as specified under the Plan. 3. Accrual for future reimbursement of the unused portion of the professional fees escrow account and other receivables. 4. Write-off of prepaid expenses primarily related to $7.5 million of prepaid premium for the Predecessor Company’s directors and officers insurance policy. 5. Application of a $3.8 million deposit held by a utility service toward the settlement of the utility service’s claims under the Plan. 6. Includes a $43.8 million decrease in accrued liabilities as a result of funding an escrow account established for the payment of professional fees, partially offset by the reinstatement of certain liabilities subject to compromise as accounts payable and accrued expenses. 7. Principal balances of $35.0 million of the New Building Note, $281.8 million of the New Convertible Notes, and the $415.0 million drawn on the New First Lien Exit Facility. 8. Reclassification of non-qualified deferred compensation plan and gas balancing liabilities from liabilities subject to compromise to other long term obligations, as these liabilities became obligations of the Successor. 9. Liabilities subject to compromise were settled as follows in accordance with the Plan (in thousands): Current maturities of long-term debt and accrued interest $ 4,179,483 Accounts payable and accrued expenses 157,422 Other long-term liabilities 9,283 Liabilities subject to compromise of the Predecessor 4,346,188 Cash payments at emergence (72,385 ) Cash proceeds from building mortgage 26,847 Write-off of prepaid accounts upon emergence (8,218 ) Accrual for future reimbursement from professional fees escrow account and other receivables 12,356 Total consideration given pursuant to the Plan: Fair value of equity issued (827,424 ) Principal value of long-term debt issued and reinstated at emergence (731,735 ) Reinstatement of liabilities subject to compromise as accounts payable and accrued expenses (37,789 ) Release of stockholder receivable (1,250 ) Application of deposit held by utility services (3,770 ) Gain on settlement of liabilities subject to compromise $ 2,702,820 10. Release of a receivable from the Predecessor’s former director and officer as outlined in the Plan. 11. The following table reconciles reorganization adjustments made to Successor common stock, warrants and additional paid in capital (in thousands): Par value of 18.9 million shares of New Common Stock issued to former holders of the Senior Secured Notes and Unsecured Notes (valued at $29.31 per share) $ 19 Fair value of warrants issued to holders of the Unsecured Notes(1) 88,382 Additional paid in capital - New Common Stock 575,144 Additional paid in capital - premium on New Convertible Notes(2) 163,879 Total Successor Company equity issued on Emergence Date $ 827,424 ____________________ (1) The fair value of the warrants was estimated using a Black-Scholes-Merton model with the following assumptions: implied stock price of the Successor Company; exercise price per share of $41.34 and $42.03 for Warrant classes A and B, respectively; expected volatility of 59.26% ; risk free interest rate, continuously compounded, of 1.36% ; and holding period of six years. (2) The fair value of the New Convertible Notes was estimated using a Monte Carlo simulation with the following assumptions; the implied Successor Company stock price; expected volatility of 56.06% ; risk free interest rate, continuously compounded, of 1.08% ; recovery rate of 15.00% ; hazard rate of 12.41% ; drop on default of 100.00% ; and termination period after four years. The premium is the difference between the fair value of the New Convertible Notes of $445.7 million and the principal value of the New Convertible Notes of $281.8 million . Fresh Start Adjustments 12. Adjustments and reclassifications of derivative contracts based on their Emergence Date fair values, which were determined using the fair value methodology for commodity derivative contracts discussed in Note 6. 13. Fair value adjustment to other current assets to record assets held for sale at their anticipated sales prices. 14. Fair value adjustments to oil and natural gas properties, including asset retirement obligation, associated inventory, unproved acreage and seismic. See above for detailed discussion of fair value methodology. 15. Adjustments to other property, plant and equipment to record the assets at their respective fair values on the Emergence Date. A combination of the cost approach and income approach were utilized to determine the fair values of the Company’s headquarters and other properties located in downtown Oklahoma City, Oklahoma, and the cost approach was utilized to determine the fair value of all other property, plant and equipment. 16. Fair value adjustments to the Company’s asset retirement obligations as a result of applying fresh start accounting. Upon implementation of fresh start accounting, the Company revalued these obligations based upon updates to wells’ productive lives and application of the Successor Company’s credit adjusted risk fee rate. 17. Fair value adjustment to record premium on the New Building Note. 18. Cancellation of Predecessor Company’s common stock, preferred stock, treasury stock and paid-in capital. 19. Adjustment to reset retained deficit to zero . 20. Elimination of the Predecessor non-controlling interest.
Reorganization Items	The following table summarizes reorganization items for the Predecessor 2016 Period (in thousands): Unamortized long-term debt $ 3,546,847 Litigation claims (20,478 ) Rejections and cures of executory contracts (16,038 ) Ad valorem and franchise taxes (3,494 ) Legal and professional fees and expenses (44,920 ) Write off of director and officer insurance policy (7,533 ) Gain on accounts payable settlements 84,228 Loss on mortgage (8,153 ) Gain on preferred stock dividends 37,893 Fresh start valuation adjustments (28,549 ) Fair value of equity issued (827,424 ) Principal value of New Convertible Notes issued (281,780 ) Gain on reorganization items, net $ 2,430,599

Summary of Significant Accoun32

Summary of Significant Accounting Policies Summary (Tables)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Schedules of Concentration of Risk	The Company had sales exceeding 10% of total revenues to the following oil and natural gas purchasers (in thousands): Sales % of Revenue Period from October 2, 2016 through December 31, 2016 - Successor Targa Pipeline Mid-Continent West OK LLC $ 35,845 36.4 % Plains Marketing, L.P. $ 32,022 32.5 % Period from January 1, 2016 through October 1, 2016 - Predecessor Plains Marketing, L.P. $ 110,370 37.6 % Targa Pipeline Mid-Continent West OK LLC $ 108,238 36.8 % December 31, 2015 - Predecessor Plains Marketing, L.P. $ 318,018 41.4 % Targa Pipeline Mid-Continent West OK LLC $ 231,649 30.1 % December 31, 2014 - Predecessor Plains Marketing, L.P. $ 597,117 38.3 % Targa Pipeline Mid-Continent West OK LLC $ 333,027 21.4 %

Supplemental Cash Flow Inform33

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2016
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	Supplemental disclosures to the consolidated statements of cash flows are presented below (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Supplemental Disclosure of Cash Flow Information Cash paid for reorganization items $ — $ (55,606 ) $ — $ — Cash paid for interest, net of amounts capitalized $ (1,183 ) $ (104,609 ) $ (296,386 ) $ (235,793 ) Cash (paid) received for income taxes $ — $ (28 ) $ (88 ) $ 1,928 Supplemental Disclosure of Noncash Investing and Financing Activities Cumulative effect of adoption of ASU 2015-02 $ — $ (247,566 ) $ — $ — Property, plant and equipment transferred in settlement of contract $ — $ 215,635 $ — $ — Change in accrued capital expenditures $ 10,630 $ 25,045 $ 177,586 $ (55,557 ) Equity issued for debt $ (13,001 ) $ (4,409 ) $ (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 ) $ —

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Significant Unobservable Inputs - Liabilities	Th e 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) 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, 2016 - Successor Fair Value Measurements Netting(1) Assets/Liabilities at Fair Value Level 1 Level 2 Level 3 Assets Investments $ 7,541 $ — $ — $ — $ 7,541 $ 7,541 $ — $ — $ — $ 7,541 Liabilities Commodity derivative contracts $ — $ 29,714 $ — $ — $ 29,714 $ — $ 29,714 $ — $ — $ 29,714 December 31, 2015 - Predecessor 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 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 ____________________ (1) Represents the impact of netting assets and liabilities with counterparties where the right of offset exists.
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 debt holder conversion features (in thousands): Predecessor Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Beginning balance $ 29,355 $ — Issuances — 31,200 (Loss) gain on derivative holder conversion feature (880 ) 10,198 Conversions (21,194 ) (12,043 ) Write off of derivative holder conversion feature to reorganization items (7,281 ) — Ending level 3 debt holder conversion feature balance $ — $ 29,355
Estimated Fair Value and Carrying Value of the Company's Notes	The estimated fair values and carrying values of the Company’s notes are as follows (in thousands): Successor Predecessor December 31, 2016 December 31, 2015 Fair Value Carrying Value Fair Value Carrying Value New Convertible Notes $ 334,800 $ 268,780 $ — $ — New Building Note $ 40,608 $ 36,528 $ — $ — 8.75% Senior Secured Notes due 2020 $ — $ — $ 403,098 $ 1,265,814 Senior Unsecured Notes 8.75% Senior Notes due 2020 $ — $ — $ 39,740 $ 389,232 7.5% Senior Notes due 2021 $ — $ — $ 79,812 $ 751,087 8.125% Senior Notes due 2022 $ — $ — $ 57,749 $ 518,693 7.5% Senior Notes due 2023 $ — $ — $ 58,799 534,869 Convertible Senior Unsecured Notes 8.125% Convertible Senior Notes due 2022 $ — $ — $ 44,199 $ 78,290 7.5% Convertible Senior Notes due 2023 $ — $ — $ 15,125 $ 24,393

Accounts Receivable (Tables)

Accounts Receivable (Tables)	12 Months Ended
	Dec. 31, 2016
Receivables [Abstract]
Summary of Accounts Receivable	A summary of accounts receivable is as follows (in thousands): Successor Predecessor December 31, December 31, 2016 2015 Oil, natural gas and NGL sales $ 42,631 $ 61,140 Joint interest billing 17,338 60,403 Oil and natural gas services 736 2,417 Other 14,272 8,274 Total accounts receivable 74,977 132,234 Less: allowance for doubtful accounts (880 ) (4,847 ) Total accounts receivable, net $ 74,097 $ 127,387
Balance and Activity in Allowance for Doubtful Accounts	The following table presents the balance and activity in the allowance for doubtful accounts for the Successor 2016 Period, the Predecessor 2016 Period and years ended December 31, 2015 and 2014 (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Beginning balance $ — $ 4,847 $ 7,083 $ 11,061 Additions charged to costs and expenses(1) 880 16,695 1,320 818 Deductions(2) — (751 ) (3,556 ) (4,796 ) Impact of fresh start accounting — (20,791 ) — — Ending balance $ 880 $ — $ 4,847 $ 7,083 ____________________ (1) The Predecessor 2016 Period includes an addition for a joint interest account receivable after a determination that future collection was doubtful. (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, 2016
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment consists of the following (in thousands): Successor Predecessor December 31, December 31, 2016 2015 Oil and natural gas properties Proved(1) $ 840,201 $ 12,529,681 Unproved 74,937 363,149 Total oil and natural gas properties 915,138 12,892,830 Less accumulated depreciation, depletion and impairment (353,030 ) (11,149,888 ) Net oil and natural gas properties capitalized costs 562,108 1,742,942 Land 5,100 14,260 Non-oil and natural gas equipment(2) 166,010 373,687 Buildings and structures(3) 88,603 227,673 Total 259,713 615,620 Less accumulated depreciation and amortization (3,889 ) (123,860 ) Other property, plant and equipment, net 255,824 491,760 Total property, plant and equipment, net $ 817,932 $ 2,234,702 ____________________ (1) No interest was capitalized for the Successor 2016 Period. Includes cumulative capitalized interest of approximately $48.9 million at December 31, 2015. (2) No interest was capitalized for the Successor 2016 Period. Includes cumulative capitalized interest of approximately $4.3 million at December 31, 2015. (3) No interest was capitalized for the Successor 2016 Period. Includes cumulative capitalized interest of approximately $20.4 million at December 31, 2015.
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, 2016 (in thousands): Year Cost Incurred Total 2016 2015 2014 2013 and Prior Property acquisition $ 71,171 $ 7,390 $ 18,959 $ 34,770 $ 10,052 Exploration(1) 20,459 2,123 10,578 4,678 3,080 Total costs incurred $ 91,630 $ 9,513 $ 29,537 $ 39,448 $ 13,132 ____________________ (1) Includes $16.7 million of pipe inventory costs incurred ( $2.1 million in 2016 , $9.6 million in 2015 and $5.0 million in 2014 and prior years).

Impairment (Tables)

Impairment (Tables)	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
Schedule of Impairment by Asset Class	Impairment consists of the following (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Full cost pool ceiling limitation(1)(2)(3) $ 319,087 $ 657,392 $ 4,473,787 $ 164,779 Drilling assets(4) — 3,511 37,646 27,428 Electrical transmission assets(5) — 55,600 — — Midstream assets(6) — 1,691 7,148 561 Other(7) — — 16,108 — $ 319,087 $ 718,194 $ 4,534,689 $ 192,768 ____________________ (1) Impairment recorded in the Successor 2016 Period resulted from the application of fresh start accounting. Upon the application of fresh start accounting, the value of the Successor Company full cost pool was determined based upon forward strip oil and natural gas prices as of the Emergence Date. Because these prices were higher than the 12-month weighted average prices used in the full cost ceiling limitation calculation at December 31, 2016, the Successor Company incurred a ceiling test impairment. (2) Impairment recorded for the Predecessor Company in 2016 was due to full cost ceiling limitations recognized in each of the first three quarters of 2016. The impairments recorded in 2015 and the first two quarters of 2016 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 throughout 2015 and the first half of 2016. The impairment recorded in the third quarter of 2016 resulted primarily from downward revisions to forecasted reserves due to a decrease in projected Mid-Continent production volumes. (3) Impairment in 2014 resulted from the divestiture of the Gulf Properties. (4) Impairment recorded in the Predecessor 2016 Period and the year ended December 31, 2015, resulted from discontinued drilling operations in its Permian region which resulted in an impairment on certain drilling assets after determining their future use was limited. During 2014, the Company recorded a $24.3 million impairment on its drilling and oilfield services assets in the Permian region as a result of fulfilling its drilling obligation with the Permian Trust in 2014 and the downward trend in oil prices that began in the second half of 2014. (5) Impairment in the Predecessor 2016 Period resulted from a decrease in projected Mid-Continent production volumes supporting the system’s usage. (6) Impairment in the Predecessor 2016 Period and the years ended December 31, 2015 and 2014 resulted from the evaluation of certain midstream pipe inventory, natural gas compressors, gas treating plants and a carbon dioxide (“CO 2 ”) compressor station after determining that their future use was limited. (7) Impairment recorded on other assets in 2015, includes a $15.4 million impairment on property located in downtown Oklahoma City, Oklahoma to adjust the carrying value of the property to the agreed upon sales price for which it was later sold in 2016.

Accounts Payable and Accrued 38

Accounts Payable and Accrued Expenses (Tables)	12 Months Ended
	Dec. 31, 2016
Payables and Accruals [Abstract]
Accounts Payable and Accrued Expenses	Accounts payable and accrued expenses consist of the following (in thousands): Successor Predecessor December 31, December 31, 2016 2015 Accounts payable and other accrued expenses $ 65,408 $ 231,697 Accrued interest 648 73,320 Production payable 16,011 55,260 Payroll and benefits 33,606 42,728 Convertible perpetual preferred stock dividends — 21,572 Drilling advances 844 2,295 Related party — 1,545 Total accounts payable and accrued expenses $ 116,517 $ 428,417

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Long-Term Debt	Long-term debt consists of the following (in thousands): Successor Predecessor December 31, December 31, 2016 2015 New First Lien Exit Facility $ — $ — New Convertible Notes 268,780 — New Building Note 36,528 — Senior credit facility — — 8.75% Senior Secured Notes due 2020 — 1,265,814 Senior Unsecured Notes 8.75% Senior Notes due 2020 — 389,232 7.5% Senior Notes due 2021 — 751,087 8.125% Senior Notes due 2022 — 518,693 7.5% Senior Notes due 2023 — 534,869 Convertible Senior Unsecured Notes 8.125% Convertible Senior Notes due 2022 — 78,290 7.5% Convertible Senior Notes due 2023 — 24,393 Total debt 305,308 3,562,378 Less: current maturities of long-term debt — — Long-term debt $ 305,308 $ 3,562,378

Derivatives (Tables)

Derivatives (Tables)	12 Months Ended
	Dec. 31, 2016
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 New First Lien Exit Facility and senior credit facility (in thousands): December 31, 2016 - Successor Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount Assets Derivative contracts - current $ — $ — $ — $ — $ — Derivative contracts - noncurrent — — — — — Total $ — $ — $ — $ — $ — Liabilities Derivative contracts - current $ 27,538 $ — $ 27,538 $ (27,538 ) $ — Derivative contracts - noncurrent 2,176 — 2,176 (2,176 ) — Total $ 29,714 $ — $ 29,714 $ (29,714 ) $ — December 31, 2015 - Predecessor 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 ) $ —
Open Oil and Natural Gas Commodity Derivative Contracts	At December 31, 2016 , the Company’s open commodity derivative contracts consisted of the following: Oil Price Swaps Notional (MBbls) Weighted Average Fixed Price January 2017 - December 2017 3,285 $ 52.24 January 2018 - December 2018 1,825 $ 55.34 Natural Gas Price Swaps Notional (MMcf) Weighted Average Fixed Price January 2017 - December 2017 32,850 $ 3.20 January 2018 - December 2018 3,650 $ 3.12
Fair Value of Derivative Contracts	The following table presents the fair value of the Company’s derivative contracts on a gross basis without regard to same-counterparty netting (in thousands): Successor Predecessor December 31, December 31, Type of Contract Balance Sheet Classification 2016 2015 Derivative assets Oil price swaps Derivative contracts - current $ — $ 68,224 Oil collars—three way Derivative contracts - current — 17,300 Derivative liabilities Oil price swaps Derivative contracts - current (13,395 ) — Natural gas price swaps Derivative contracts - current (14,143 ) — Natural gas basis swaps Derivative contracts - current — (1,748 ) Debt holder conversion feature Current maturities of long-term debt — (29,355 ) Mandatory prepayment feature - PGC Senior Secured Notes Current maturities of long-term debt — (2,941 ) Oil price swaps Derivative contracts - noncurrent (2,105 ) — Natural gas price swaps Derivative contracts - noncurrent (71 ) — Total net derivative contracts $ (29,714 ) $ 51,480

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2016
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 (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Beginning balance $ 92,413 $ 103,578 $ 54,402 $ 424,117 Liability incurred upon acquiring and drilling wells 121 505 1,662 4,968 Revisions in estimated cash flows(1) 12,397 — 44,060 (5,848 ) Liability settled or disposed in current period(2) (540 ) (36,979 ) (1,023 ) (377,927 ) Accretion 2,090 4,365 4,477 9,092 Impact of fresh start accounting — 20,944 — — Ending balance 106,481 92,413 103,578 54,402 Less: current portion 66,154 65,678 8,399 — Asset retirement obligations, net of current $ 40,327 $ 26,735 $ 95,179 $ 54,402 ____________________ (1) Revisions for the Successor 2016 Period and the year ended December 31, 2015 relate primarily to changes in estimated well lives. (2) Liability settled or disposed for the Predecessor 2016 Period includes $34.1 million associated with the WTO Properties sold in January 2016. Liability settled or disposed for the year ended December 31, 2014, includes $366.0 million associated with the Gulf Properties sold in February 2014. For further discussion of the sale of properties see Note 5 .

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Preferred Stock Terms	The following table summarizes information about each series of the Predecessor 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 are as follows (in thousands): Predecessor Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 8.5% Convertible perpetual preferred stock Dividends paid in cash $ — $ 11,262 $ 22,525 Dividends satisfied in shares of common stock(1) $ — $ 11,262 $ — Accrued dividends at period end $ — $ 8,447 $ 8,447 Dividends in arrears $ 11,262 $ — $ — 7.0% Convertible perpetual preferred stock Dividends paid in cash $ — $ — $ 21,000 Dividends satisfied in shares of common stock(2) $ — $ 10,500 $ — Accrued dividends at period end $ — $ 13,125 $ 2,625 Dividends in arrears $ 21,000 $ 10,500 $ — 6.0% Convertible perpetual preferred stock Dividends paid in cash $ — $ — $ 12,000 Accrued dividends at period end $ — $ — $ — ____________________ (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 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 consolidated statement of operations.
Treasury Stock Activity	The following table shows the number of shares withheld for taxes and the associated value of those shares (in thousands). These shares were accounted for as treasury stock when withheld, and then immediately retired. Predecessor Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Number of shares withheld for taxes 1,122 1,872 1,034 Value of shares withheld for taxes $ 44 $ 2,428 $ 6,373

Share-Based Compensation (Table

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of Unvested Restricted Stock Awards	The following table presents a summary of the Predecessor Company’s unvested restricted stock awards. Number of Shares Weighted- Average Grant Date Fair Value (In thousands) 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 Granted — $ — Vested (3,034 ) $ 5.34 Forfeited / Canceled (2,592 ) $ 4.31 Predecessor ending unvested restricted shares at October 1, 2016 — $ — The following table presents a summary of the Successor Company’s unvested restricted stock awards. Number of Shares Weighted- Average Grant Date Fair Value (In thousands) Unvested restricted shares outstanding at October 1, 2016 — $ — Granted 1,448 $ 24.32 Vested (14 ) $ 24.32 Forfeited / Canceled (27 ) $ 24.32 Unvested restricted shares outstanding at December 31, 2016 1,407 $ 24.32

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
(Benefit) Provision for Income Taxes	The Company’s income tax provision (benefit) consisted of the following components (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Current Federal $ — $ — $ — $ (1,160 ) State 9 11 123 (1,133 ) 9 11 123 (2,293 ) Deferred Federal — — — — State — — — — — — — — Total provision (benefit) 9 11 123 (2,293 ) Less: income tax provision attributable to noncontrolling interest — — 90 283 Total provision (benefit) attributable to SandRidge Energy, Inc. $ 9 $ 11 $ 33 $ (2,576 )
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 provision (benefit) is as follows (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Computed at federal statutory rate $ (116,891 ) $ 504,283 $ (1,512,325 ) $ 122,362 State taxes, net of federal benefit (3,696 ) 10,512 (19,988 ) 4,145 Non-deductible expenses 144 462 816 1,895 Non-deductible debt costs — 22,694 10,228 — Stock-based compensation 306 5,884 6,700 1,467 Net effects of consolidating the non-controlling interests’ tax provisions — — 218,196 (34,614 ) Discharge of debt and other reorganization related items — 359,278 — — Change in valuation allowance 120,144 (903,102 ) 1,296,405 (96,769 ) Other 2 — 1 (1,062 ) Total provision (benefit) attributable to SandRidge Energy, Inc. $ 9 $ 11 $ 33 $ (2,576 )
Deferred Tax Assets and Liabilities	Significant components of the Company’s deferred tax assets and liabilities are as follows (in thousands): Successor Predecessor December 31, 2016 December 31, 2015 Deferred tax liabilities Investments(1) $ 275,128 $ 138,310 Derivative contracts — 30,989 Long-term debt — 10,017 Total deferred tax liabilities 275,128 179,316 Deferred tax assets Property, plant and equipment 751,683 807,275 Derivative contracts 11,274 — Allowance for doubtful accounts 1,487 18,702 Net operating loss carryforwards 527,079 1,190,799 Compensation and benefits 14,494 18,607 Alternative minimum tax credits and other carryforwards 43,770 44,302 Asset retirement obligations 40,399 38,314 CO 2 under-delivery shortfall penalty — 40,654 Other 4,663 4,305 Total deferred tax assets 1,394,849 2,162,958 Valuation allowance (1,119,721 ) (1,983,642 ) Net deferred tax liability $ — $ — ____________________ (1) Includes the Company’s deferred tax liability resulting from its investment in the Royalty Trusts.
Unrecognized Tax Benefits	A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Unrecognized tax benefit at January 1 $ 81 $ 81 $ 77 Changes to unrecognized tax benefits related to a prior year 3 — 4 Unrecognized tax benefit at December 31 $ 84 $ 81 $ 81

(Loss) Earnings per Share (Tabl

(Loss) Earnings per Share (Tables)	12 Months Ended
	Dec. 31, 2016
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 (loss) earnings per share: Net (Loss) Income Weighted Average Shares (Loss) Earnings Per Share (In thousands, except per share amounts) Period from October 2, 2016 to December 31, 2016 (Successor) Basic loss per share $ (333,982 ) 18,967 $ (17.61 ) Effect of dilutive securities Restricted stock(1) — — Warrants(1) — — New Convertible Notes(2) — — Diluted loss per share $ (333,982 ) 18,967 $ (17.61 ) Period from January 1, 2016 to October 1, 2016 (Predecessor) Basic earnings per share $ 1,424,476 708,928 $ 2.01 Effect of dilutive securities Restricted stock and units(3) — — Diluted earnings per share $ 1,424,476 708,928 $ 2.01 Year Ended December 31, 2015 (Predecessor) Basic loss per share $ (3,735,495 ) 521,936 $ (7.16 ) Effect of dilutive securities Restricted stock and units(3) — — Convertible preferred stock(4) — — Convertible senior unsecured notes(5) — — Diluted loss per share $ (3,735,495 ) 521,936 $ (7.16 ) Year Ended December 31, 2014 (Predecessor) Basic earnings per share $ 203,260 479,644 $ 0.42 Effect of dilutive securities Restricted stock — 2,181 Convertible preferred stock(4) 6,500 17,918 Diluted earnings per share $ 209,760 499,743 $ 0.42 ____________________ (1) No incremental shares of potentially dilutive restricted stock awards or warrants were included for the Successor 2016 Period as their effect was antidilutive. (2) Potential common shares related to the New Convertible Notes covering 14.6 million shares for the Successor 2016 Period were excluded from the computation of loss per share because their effect would have been antidilutive under the if-converted method. (3) No incremental shares of potentially dilutive restricted stock awards or units were included for the Predecessor 2016 Period and the year ended December 31, 2015 as their effect was antidilutive under the treasury stock method. (4) Potential common shares related to the Predecessor Company’s then-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. (5) Potential common shares related to the Predecessor Company’s then-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.

Supplemental Information on O46

Supplemental Information on Oil and Natural Gas Producing Activities (Tables)	12 Months Ended
	Dec. 31, 2016
Extractive Industries [Abstract]
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): Successor Predecessor December 31, December 31, 2016 2015 2014 Oil and natural gas properties Proved $ 840,201 $ 12,529,681 $ 11,707,147 Unproved 74,937 363,149 290,596 Total oil and natural gas properties 915,138 12,892,830 11,997,743 Less accumulated depreciation, depletion and impairment (353,030 ) (11,149,888 ) (6,359,149 ) Net oil and natural gas properties capitalized costs $ 562,108 $ 1,742,942 $ 5,638,594
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): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Acquisitions of properties Proved $ 5,142 $ 3,897 $ 35,376 $ 73,370 Unproved 5,491 1,899 210,065 123,649 Exploration(1) — 1,234 29,297 41,070 Development 27,429 149,924 571,562 1,288,395 Total cost incurred $ 38,062 $ 156,954 $ 846,300 $ 1,526,484 ____________________ (1) Includes seismic costs of $7.1 million and $10.8 million for the years ended December 31, 2015 and 2014 , 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 are shown in the following table (in thousands): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Revenues $ 98,307 $ 279,971 $ 707,434 $ 1,420,879 Expenses Production costs 27,640 135,715 324,141 377,819 Depreciation and depletion 33,971 86,613 319,913 434,295 Accretion of asset retirement obligations 2,090 4,365 4,477 9,092 Impairment 319,087 657,392 4,473,787 164,779 Total expenses 382,788 884,085 5,122,318 985,985 (Loss) income before income taxes (284,481 ) (604,114 ) (4,414,884 ) 434,894 Income tax expense (benefit)(1) 8 (5 ) 126 (2,852 ) Results of operations for oil and natural gas producing activities (excluding corporate overhead and interest costs) $ (284,489 ) $ (604,109 ) $ (4,415,010 ) $ 437,746 ____________________ (1) 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. Oil NGL Natural Gas (MBbls) (MBbls) (MMcf)(1) Proved developed and undeveloped reserves As of December 31, 2013 - Predecessor 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) - Predecessor 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) - Predecessor 77,911 61,075 1,113,840 Adoption of ASU 2015-02 (6,971 ) (3,695 ) (50,508 ) Revisions of previous estimates (39,973 ) (21,475 ) (415,568 ) Extensions and discoveries 987 472 7,955 Sales of reserves in place (387 ) — (145,267 ) Production (4,315 ) (3,358 ) (44,124 ) As of October 1, 2016 - Predecessor 27,252 33,019 466,328 Revisions of previous estimates 23,978 1,139 915 Extensions and discoveries 2,868 448 10,309 Production (1,214 ) (999 ) (12,770 ) As of December 31, 2016 - Successor 52,884 33,607 464,782 Proved developed reserves As of December 31, 2013 - Predecessor 83,893 35,807 951,609 As of December 31, 2014 - Predecessor 79,022 56,823 1,203,447 As of December 31, 2015 - Predecessor 48,639 51,089 964,617 As of October 1, 2016 - Predecessor 24,541 30,238 428,050 As of December 31, 2016 - Successor 25,911 29,290 393,028 Proved undeveloped reserves As of December 31, 2013 - Predecessor 58,748 23,245 438,820 As of December 31, 2014 - Predecessor 47,009 34,963 584,786 As of December 31, 2015 - Predecessor 29,272 9,986 149,223 As of October 1, 2016 - Predecessor 2,711 2,781 38,278 As of December 31, 2016 - Successor 26,973 4,317 71,754 ____________________ (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 as shown in the table below: Predecessor December 31, 2015 2014 Oil (MBbl) 7,004 11,027 NGL (MBbl) 3,694 4,761 Natural gas (MMcf) 50,508 70,833
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: Successor Predecessor December 31, December 31, 2016 2015 2014 Oil (per barrel) $ 38.59 $ 45.29 $ 91.65 NGL (per barrel) $ 10.99 $ 12.68 $ 32.79 Natural gas (per Mcf) $ 1.56 $ 1.87 $ 3.61
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). Successor Predecessor December 31, December 31, 2016 2015 2014 Future cash inflows from production $ 3,136,762 $ 6,387,944 $ 21,022,320 Future production costs (1,454,798 ) (2,731,542 ) (6,499,366 ) Future development costs(1) (665,516 ) (838,945 ) (1,810,201 ) Future income tax expenses (142 ) (901 ) (3,223,740 ) Undiscounted future net cash flows 1,016,306 2,816,556 9,489,013 10% annual discount (577,942 ) (1,501,994 ) (5,401,261 ) Standardized measure of discounted future net cash flows(2) $ 438,364 $ 1,314,562 $ 4,087,752 ____________________ (1) Includes abandonment costs. (2) Includes approximately $224.6 million and $643.3 million attributable to noncontrolling interests at December 31, 2015 and 2014 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): Successor Predecessor Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Year Ended December 31, 2014 Beginning present value $ 392,604 $ 1,314,562 $ 4,087,752 $ 4,017,611 Changes during the year Adoption of ASU 2015-02 — (224,965 ) — — Revenues less production and other costs (70,668 ) (144,256 ) (383,293 ) (1,043,060 ) Net changes in prices, production and other costs 35,684 (394,173 ) (3,813,465 ) 331,694 Development costs incurred 7,941 69,080 217,596 364,262 Net changes in future development costs (291,232 ) 436,041 273,437 (341,183 ) Extensions and discoveries 14,986 12,449 230,055 1,785,963 Revisions of previous quantity estimates 308,374 (728,254 ) (1,354,778 ) (77,688 ) Accretion of discount 9,375 91,337 512,483 477,458 Net change in income taxes — 402 1,426,333 (256,371 ) Purchases of reserves in-place — — 18,429 50,958 Sales of reserves in-place — (13,314 ) — (1,058,330 ) Timing differences and other(1) 31,300 (26,305 ) 100,013 (163,562 ) Net change for the year 45,760 (921,958 ) (2,773,190 ) 70,141 Ending present value(2) $ 438,364 $ 392,604 $ 1,314,562 $ 4,087,752 ____________________ (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 and $643.3 million attributable to noncontrolling interests at December 31, 2015 , and 2014 respectively.

Quarterly Financial Results (47

Quarterly Financial Results (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Results (Unaudited)	The Company’s operating results for each quarter of 2016 and 2015 are summarized below (in thousands, except per share data). Predecessor Successor First Quarter Second Quarter Third Quarter Fourth Quarter Fourth Quarter 2016 Total revenues $ 90,332 $ 99,421 $ 104,056 $ — $ 98,456 Loss from operations(1)(2) $ (273,555 ) $ (275,310 ) $ (357,338 ) $ — $ (336,345 ) Net (loss) income(1)(2)(3) $ (313,226 ) $ (515,911 ) $ (404,337 ) $ 2,674,271 (333,982 ) (Loss applicable) income available to SandRidge Energy, Inc. common stockholders(1)(2)(3) $ (324,107 ) $ (521,351 ) $ (404,337 ) $ 2,674,271 $ (333,982 ) (Loss applicable) income available per share to SandRidge Energy, Inc. common stockholders Basic $ (0.47 ) $ (0.73 ) $ (0.56 ) $ 3.72 $ (17.61 ) Diluted $ (0.47 ) $ (0.73 ) $ (0.56 ) $ 3.72 $ (17.61 ) Predecessor First Quarter Second Quarter Third Quarter Fourth Quarter 2015 Total revenues $ 215,308 $ 229,607 $ 180,152 $ 143,642 Loss from operations(4)(5) $ (1,088,456 ) $ (1,535,083 ) $ (1,059,733 ) $ (959,406 ) Net loss(4)(5) $ (1,151,874 ) $ (1,588,731 ) $ (796,485 ) $ (783,961 ) Loss applicable to SandRidge Energy, Inc. common stockholders(4)(5) $ (1,045,834 ) $ (1,375,556 ) $ (649,526 ) $ (664,579 ) Loss applicable per share to SandRidge Energy, Inc. common stockholders(6) Basic $ (2.19 ) $ (2.78 ) $ (1.23 ) $ (1.13 ) Diluted $ (2.19 ) $ (2.78 ) $ (1.23 ) $ (1.13 ) ____________________ (1) Includes impairment of $110.1 million , $253.6 million , $354.5 million and $319.1 million for the first, second, and third quarters and Successor 2016 Period, respectively. See Note 9 for further discussion of impairment. (2) Includes loss on settlement of contract of $89.1 million and gain on extinguishment of $41.3 million for the first quarter. (3) Includes (loss) gain on reorganization items related to the Company’s restructuring under Chapter 11 filings of $(200.9) million , $(42.8) million , and $2.7 billion for the second and third quarters and Predecessor fourth quarter, respectively. See Note 2 for further discussion of reorganization items. (4) 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 9 for further discussion of impairment. (5) 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. (6) Loss applicable 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 per share to common stockholders for each of the four quarters may not equal the fiscal year amount.

Voluntary Reorganization unde48

Voluntary Reorganization under Chapter 11 Proceedings - Narrative (Details) $ / shares in Units, shares in Millions	Oct. 01, 2016USD ($)sharesdirector$ / shares	Oct. 01, 2016USD ($)director$ / sharesshares	Dec. 31, 2015USD ($)	Oct. 31, 2015USD ($)	Jun. 30, 2015USD ($)
New First Lien Exit Facility | Revolving Credit Facility
Restructuring Cost and Reserve [Line Items]
Maximum borrowing capacity	$ 425,000,000	$ 425,000,000
7.0% Convertible perpetual preferred stock
Restructuring Cost and Reserve [Line Items]
Preferred stock, dividend rate, percentage			7.00%
8.5% Convertible perpetual preferred stock
Restructuring Cost and Reserve [Line Items]
Preferred stock, dividend rate, percentage			8.50%
Predecessor
Restructuring Cost and Reserve [Line Items]
Face value of long-term debt			$ 3,562,378,000
Predecessor | Convertible Debt
Restructuring Cost and Reserve [Line Items]
Notes exchanged/converted		$ 232,100,000	255,300,000
Predecessor | New First Lien Exit Facility | Revolving Credit Facility
Restructuring Cost and Reserve [Line Items]
Face value of long-term debt			$ 0
Predecessor | 8.75% Senior Secured Notes due 2020 | Secured Notes
Restructuring Cost and Reserve [Line Items]
Long-term debt, fixed interest rate	8.75%	8.75%	8.75%		8.75%
Face amount of debt instrument				$ 78,000,000	$ 1,250,000,000
Face value of long-term debt			$ 1,265,814,000
Predecessor | New Building Note | Secured Notes
Restructuring Cost and Reserve [Line Items]
Face value of long-term debt			$ 0
Predecessor | 8.75% Senior Notes due 2020 | Senior Notes
Restructuring Cost and Reserve [Line Items]
Long-term debt, fixed interest rate	8.75%	8.75%	8.75%
Face value of long-term debt			$ 389,232,000
Predecessor | 7.5% Senior Notes due 2021 | Senior Notes
Restructuring Cost and Reserve [Line Items]
Long-term debt, fixed interest rate	7.50%	7.50%	7.50%
Face value of long-term debt			$ 751,087,000
Predecessor | 8.125% Senior Notes due 2022 | Senior Notes
Restructuring Cost and Reserve [Line Items]
Long-term debt, fixed interest rate	8.125%	8.125%	8.125%
Face value of long-term debt			$ 518,693,000
Predecessor | 8.125% Convertible Senior Notes due 2022
Restructuring Cost and Reserve [Line Items]
Long-term debt, fixed interest rate			8.125%
Predecessor | 8.125% Convertible Senior Notes due 2022 | Convertible Debt
Restructuring Cost and Reserve [Line Items]
Long-term debt, fixed interest rate	8.125%	8.125%	8.125%
Notes exchanged/converted		$ 200,500,000	$ 186,600,000
Face value of long-term debt			$ 78,290,000
Predecessor | 7.5% Convertible Senior Notes due 2023
Restructuring Cost and Reserve [Line Items]
Long-term debt, fixed interest rate			7.50%
Predecessor | 7.5% Convertible Senior Notes due 2023 | Convertible Debt
Restructuring Cost and Reserve [Line Items]
Long-term debt, fixed interest rate	7.50%	7.50%	7.50%
Notes exchanged/converted		$ 31,600,000	$ 68,700,000
Face value of long-term debt			$ 24,393,000
Predecessor | 7.5% Senior Notes due 2023 | Senior Notes
Restructuring Cost and Reserve [Line Items]
Long-term debt, fixed interest rate	7.50%	7.50%	7.50%
Face value of long-term debt			$ 534,869,000
Predecessor | 7.0% Convertible perpetual preferred stock
Restructuring Cost and Reserve [Line Items]
Preferred stock, dividend rate, percentage	7.00%		7.00%
Predecessor | 8.5% Convertible perpetual preferred stock
Restructuring Cost and Reserve [Line Items]
Preferred stock, dividend rate, percentage	8.50%		8.50%
Predecessor | Plan of Reorganization
Restructuring Cost and Reserve [Line Items]
Number of employee directors | director	5	5
Number of non-employee directors | director	4	4
Predecessor | Plan of Reorganization | Holders of Senior Credit Facility | Revolving Credit Facility
Restructuring Cost and Reserve [Line Items]
Cash payments for prepetition obligations	$ 35,000,000	$ 35,000,000
Predecessor | Plan of Reorganization | Holders of Senior Secured Notes | Convertible Debt
Restructuring Cost and Reserve [Line Items]
Face amount of debt instrument	$ 281,800,000	$ 281,800,000
Annual interest rate	0.00%	0.00%
Number of shares issuable under convertible securities | shares	15
Predecessor | Plan of Reorganization | Holders of Unsecured Claims
Restructuring Cost and Reserve [Line Items]
Cash payments for prepetition obligations	$ 36,700,000	$ 36,700,000
Predecessor | Plan of Reorganization | Series A Warrants | Holders of Unsecured Claims
Restructuring Cost and Reserve [Line Items]
Number of shares to be issued | shares	4.9	4.9
Shares issued | shares	4.5
Exercise price of warrants (in usd per share) | $ / shares	$ 41.34	$ 41.34
Predecessor | Plan of Reorganization | Series B Warrants | Holders of Unsecured Claims
Restructuring Cost and Reserve [Line Items]
Number of shares to be issued | shares	2.1	2.1
Shares issued | shares	1.9
Exercise price of warrants (in usd per share) | $ / shares	$ 42.03	$ 42.03
Predecessor | Plan of Reorganization | New First Lien Exit Facility
Restructuring Cost and Reserve [Line Items]
Cash collateral	$ 50,000,000	$ 50,000,000
Cash collateral to be released upon delivery of acceptable business plan	12,500,000	12,500,000
Cash collateral to be released upon achievement for two consecutive quarters of certain milestones	12,500,000	12,500,000
Cash collateral to be released upon meeting minimum ratio of proved producing reserves to aggregate principal loan commitments	$ 25,000,000	$ 25,000,000
Minimum ratio of proved producing reserves to aggregate principal loan commitments	2	2
Predecessor | Plan of Reorganization | New First Lien Exit Facility | Revolving Credit Facility
Restructuring Cost and Reserve [Line Items]
Maximum borrowing capacity	$ 425,000,000	$ 425,000,000
Predecessor | Plan of Reorganization | 8.75% Senior Secured Notes due 2020 | Holders of Senior Secured Notes | Secured Notes
Restructuring Cost and Reserve [Line Items]
Notes exchanged/converted	78,000,000
Predecessor | Plan of Reorganization | New Building Note | Secured Notes
Restructuring Cost and Reserve [Line Items]
Face amount of debt instrument	35,000,000	$ 35,000,000
Proceeds from issuance of debt	$ 26,800,000
Predecessor | Plan of Reorganization | New Common Stock
Restructuring Cost and Reserve [Line Items]
Common stock, shares authorized | shares	18.9	18.9
Predecessor | Plan of Reorganization | New Common Stock | Holders of Senior Secured Notes
Restructuring Cost and Reserve [Line Items]
Shares issued | shares	13.7
Predecessor | Plan of Reorganization | New Common Stock | Holders of Unsecured Claims
Restructuring Cost and Reserve [Line Items]
Number of shares to be issued | shares	5.7	5.7
Shares issued | shares	5.2
Predecessor | Plan of Reorganization | 7.0% Convertible perpetual preferred stock
Restructuring Cost and Reserve [Line Items]
Preferred stock, dividend rate, percentage	7.00%
Predecessor | Plan of Reorganization | 8.5% Convertible perpetual preferred stock
Restructuring Cost and Reserve [Line Items]
Preferred stock, dividend rate, percentage	8.50%

Fresh Start Accounting - Narrat

Fresh Start Accounting - Narrative (Details) $ in Thousands	Oct. 01, 2016USD ($)
Predecessor | Minimum
Schedule of Reorganization Items [Line Items]
Estimated enterprise value	$ 1,040,000
Predecessor | Maximum
Schedule of Reorganization Items [Line Items]
Estimated enterprise value	1,320,000
Successor
Schedule of Reorganization Items [Line Items]
Enterprise value	$ 1,089,808
Discount Factor	10.00%
Fair value of proved properties	$ 632,800
Fair value of undeveloped leasehold acreage	$ 113,900

Fresh Start Accounting - Reconc

Fresh Start Accounting - Reconciliation of Enterprise Value to Fair Value (Details) - Successor - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	Dec. 31, 2016	Oct. 01, 2016
Reconciliation of Enterprise Value to Fair Value
Enterprise value		$ 1,089,808
Plus: Cash and cash equivalents	$ (121,231)	(563,372)
Less: Fair value of New Building Note		(36,610)
Less: Asset retirement obligation		(92,412)
Less: Fair value of New First Lien Exit Facility		(414,954)
Less: Fair value of New Convertible Notes		(445,660)
Less: Fair value of warrants, including warrants held in reserve for settlement of general unsecured claims		(95,794)
Fair value of Successor common stock issued upon emergence		$ 567,750
Shares issued upon emergence on October 4, 2016, including shares held in reserve for settlement of general unsecured claims	19,635	19,371
Per share value (in dollars per share)		$ 29.31

Fresh Start Accounting - Reco51

Fresh Start Accounting - Reconciliation Of Enterprise Value To Estimated Reorganization Value (Details) - Successor - USD ($) $ in Thousands	Oct. 02, 2016	Oct. 01, 2016
Reconciliation Of Enterprise Value To Estimated Reorganization Value [Line Items]
Enterprise value		$ 1,089,808
Plus: cash and cash equivalents	$ (510,532)	563,372
Plus: other working capital liabilities	195,954	131,766
Plus: other long-term liabilities	$ 8,798	8,549
Reorganization value of Successor assets		$ 1,793,495

Fresh Start Accounting - Applic

Fresh Start Accounting - Application of Fresh Start Accounting to Balance Sheet (Details) - USD ($) $ in Thousands	Oct. 02, 2016	Oct. 01, 2016
Reorganization Adjustments
Current assets
Cash and cash equivalents		$ (142,148)
Restricted cash - collateral		50,000
Restricted cash - other		2,840
Accounts receivable, net		12,356
Derivative contracts		0
Prepaid expenses		(8,218)
Other current assets		0
Total current assets		(85,170)
Oil and natural gas properties, using full cost method of accounting
Proved		0
Unproved		0
Less: accumulated depreciation, depletion and impairment		0
Net oil and natural gas properties capitalized costs		0
Noncurrent Assets
Other property, plant and equipment, net		(41)
Derivative contracts		0
Other assets		(3,770)
Total assets		(88,981)
Current liabilities
Accounts payable and accrued expenses		(14,820)
Derivative contracts		0
Asset retirement obligations		0
Total current liabilities		(14,820)
Noncurrent Liabilities
Long-term debt		731,735
Derivative contracts		0
Asset retirement obligations		0
Other long-term obligations		8,798
Liabilities subject to compromise		(4,346,188)
Total liabilities		(3,620,475)
Equity
Preferred stock		0
Common stock		19
Additional paid-in capital		739,023
Additional paid-in capital - stockholder receivable		1,250
Treasury stock, at cost		0
Warrants		88,382
Accumulated deficit		2,702,820
Total SandRidge Energy, Inc. stockholders’ (deficit) equity		3,531,494
Noncontrolling interest		0
Total stockholders’ (deficit) equity		3,531,494
Total liabilities and stockholders’ equity (deficit)		(88,981)
Fresh Start Adjustments
Current assets
Cash and cash equivalents		0
Restricted cash - collateral		0
Restricted cash - other		0
Accounts receivable, net		0
Derivative contracts		(669)
Prepaid expenses		0
Other current assets		3,217
Total current assets		2,548
Oil and natural gas properties, using full cost method of accounting
Proved		(11,344,684)
Unproved		(205,578)
Less: accumulated depreciation, depletion and impairment		11,637,538
Net oil and natural gas properties capitalized costs		87,276
Noncurrent Assets
Other property, plant and equipment, net		(93,782)
Derivative contracts		(70)
Other assets		0
Total assets		(4,028)
Current liabilities
Accounts payable and accrued expenses		0
Derivative contracts		1,666
Asset retirement obligations		57,105
Total current liabilities		58,771
Noncurrent Liabilities
Long-term debt		1,610
Derivative contracts		304
Asset retirement obligations		(36,161)
Other long-term obligations		(3)
Liabilities subject to compromise		0
Total liabilities		24,521
Equity
Preferred stock		(6)
Common stock		(718)
Additional paid-in capital		(5,315,655)
Additional paid-in capital - stockholder receivable		0
Treasury stock, at cost		5,218
Warrants		0
Accumulated deficit		5,282,591
Total SandRidge Energy, Inc. stockholders’ (deficit) equity		(28,570)
Noncontrolling interest		21
Total stockholders’ (deficit) equity		(28,549)
Total liabilities and stockholders’ equity (deficit)		(4,028)
Predecessor
Current assets
Cash and cash equivalents		652,680
Restricted cash - collateral		0
Restricted cash - other		0
Accounts receivable, net		61,446
Derivative contracts		10,192
Prepaid expenses		12,514
Other current assets		1,003
Total current assets		737,835
Oil and natural gas properties, using full cost method of accounting
Proved		12,093,492
Unproved		322,580
Less: accumulated depreciation, depletion and impairment		(11,637,538)
Net oil and natural gas properties capitalized costs		778,534
Noncurrent Assets
Other property, plant and equipment, net		357,528
Derivative contracts		70
Other assets		12,537
Total assets		1,886,504
Current liabilities
Accounts payable and accrued expenses		140,448
Derivative contracts		2,982
Asset retirement obligations		8,573
Total current liabilities		152,003
Noncurrent Liabilities
Long-term debt		0
Derivative contracts		935
Asset retirement obligations		62,896
Other long-term obligations		3
Liabilities subject to compromise		4,346,188
Total liabilities		4,562,025
Equity
Preferred stock		6
Common stock		718
Additional paid-in capital		5,315,655
Additional paid-in capital—stockholder receivable		(1,250)
Treasury stock, at cost		(5,218)
Warrants		0
Accumulated deficit		(7,985,411)
Total SandRidge Energy, Inc. stockholders’ (deficit) equity		(2,675,500)
Noncontrolling interest		(21)
Total stockholders’ (deficit) equity		(2,675,521)
Total liabilities and stockholders’ equity (deficit)		1,886,504
Predecessor | Reorganization Adjustments
Current assets
Prepaid expenses		8,218
Noncurrent Assets
Other assets		(3,770)
Noncurrent Liabilities
Liabilities subject to compromise		4,346,188
Noncurrent Liabilities
Long-term debt		731,735
Equity
Additional paid-in capital - stockholder receivable		1,250
Equity
Total SandRidge Energy, Inc. stockholders’ (deficit) equity		827,424
Successor
Current assets
Cash and cash equivalents	$ 510,532	(563,372)
Restricted cash - collateral	50,000
Restricted cash - other	2,840
Accounts receivable, net	73,802
Derivative contracts	9,523
Prepaid expenses	4,296
Other current assets	4,220
Total current assets	655,213
Oil and natural gas properties, using full cost method of accounting
Proved	748,808
Unproved	117,002
Less: accumulated depreciation, depletion and impairment	0
Net oil and natural gas properties capitalized costs	865,810
Noncurrent Assets
Other property, plant and equipment, net	263,705
Derivative contracts	0
Other assets	8,767
Total assets	1,793,495
Current liabilities
Accounts payable and accrued expenses	125,628
Derivative contracts	4,648
Asset retirement obligations	65,678
Total current liabilities	195,954	131,766
Noncurrent Liabilities
Long-term debt	733,345
Derivative contracts	1,239
Asset retirement obligations	26,735
Other long-term obligations	8,798	$ 8,549
Liabilities subject to compromise	0
Total liabilities	966,071
Equity
Preferred stock	0
Common stock	19
Additional paid-in capital	739,023
Additional paid-in capital - stockholder receivable	0
Treasury stock, at cost	0
Warrants	88,382
Accumulated deficit	0
Total SandRidge Energy, Inc. stockholders’ (deficit) equity	827,424
Noncontrolling interest	0
Total stockholders’ (deficit) equity	827,424
Total liabilities and stockholders’ equity (deficit)	$ 1,793,495

Fresh Start Accounting - Cash P

Fresh Start Accounting - Cash Payments Made Upon Emergence (Details) - Reorganization Adjustments $ in Thousands	Oct. 01, 2016USD ($)
Fresh-Start Adjustment [Line Items]
Proceeds from New Building Note	$ 26,847
Cash transferred to restricted accounts (collateral and general unsecured claims)	52,840
Payments and funding of escrow account related to professional fees	43,770
Payment on Senior Credit facility (principal and interest)	35,238
Repayment of Senior Secured Notes and Unsecured Notes	33,874
Payment of certain contract cures and other	3,273
Total uses and transfers	168,995
Net uses and transfers	$ (142,148)

Fresh Start Accounting - Reorga

Fresh Start Accounting - Reorganization Adjustments (Details) $ in Thousands	Oct. 01, 2016USD ($)
Reorganization Adjustments
Fresh-Start Adjustment [Line Items]
Increase in restricted cash - collateral	$ 50,000
Increase in restricted cash - other	2,840
Write-off of prepaid expenses	8,218
Write-off of prepaid deposit	3,770
Decrease in accrued liabilities	43,800
Increase in long-term debt	(731,735)
Reorganization Adjustments | Restricted by Debt Agreement
Fresh-Start Adjustment [Line Items]
Increase in restricted cash - collateral	50,000
Reorganization Adjustments | New Building Note | Secured Debt
Fresh-Start Adjustment [Line Items]
Increase in long-term debt	(35,000)
Reorganization Adjustments | New Convertible Notes | Convertible Debt
Fresh-Start Adjustment [Line Items]
Increase in long-term debt	(281,800)
Reorganization Adjustments | New First Lien Exit Facility | Revolving Credit Facility
Fresh-Start Adjustment [Line Items]
Increase in long-term debt	(415,000)
Write off of director and officer insurance premium
Fresh-Start Adjustment [Line Items]
Write-off of prepaid expenses	7,500
Predecessor | Reorganization Adjustments
Fresh-Start Adjustment [Line Items]
Write-off of prepaid expenses	(8,218)
Write-off of prepaid deposit	3,770
Increase in long-term debt	$ (731,735)

Fresh Start Accounting - Liabil

Fresh Start Accounting - Liabilities Subject to Compromise Settled (Details) - USD ($) $ in Thousands	Oct. 01, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Reorganization Adjustments
Fresh-Start Adjustment [Line Items]
Cash proceeds from building mortgage	$ 26,847
Write-off of prepaid accounts upon emergence	8,218	$ 8,218
Principal value of long-term debt issued and reinstated at emergence	(731,735)	(731,735)
Release of stockholder receivable	(1,250)	(1,250)
Application of deposit held by utility services	3,770	3,770
Predecessor
Fresh-Start Adjustment [Line Items]
Liabilities subject to compromise of the Predecessor	4,346,188	4,346,188
Cash proceeds from building mortgage		26,847	$ 0	$ 0
Predecessor | Reorganization Adjustments
Fresh-Start Adjustment [Line Items]
Current maturities of long-term debt and accrued interest	4,179,483	4,179,483
Accounts payable and accrued expenses	157,422	157,422
Other long-term liabilities	9,283	9,283
Liabilities subject to compromise of the Predecessor	4,346,188	4,346,188
Cash payments at emergence	(72,385)
Cash proceeds from building mortgage	26,847
Write-off of prepaid accounts upon emergence	(8,218)	(8,218)
Accrual for future reimbursement from professional fees escrow account and other receivables	12,356	12,356
Fair value of equity issued	(827,424)	(827,424)
Principal value of long-term debt issued and reinstated at emergence	(731,735)	(731,735)
Reinstatement of liabilities subject to compromise as accounts payable and accrued expenses	(37,789)	(37,789)
Release of stockholder receivable	(1,250)	(1,250)
Application of deposit held by utility services	3,770	3,770
Gain on settlement of liabilities subject to compromise	$ 2,702,820	$ 2,702,820

Fresh Start Accounting - Reor56

Fresh Start Accounting - Reorganization Adjustments to Equity (Details) - Reorganization Adjustments $ / shares in Units, $ in Thousands	Oct. 01, 2016USD ($)$ / shares
Debtor Reorganization Adjustments, Equity [Abstract]
Par value of 18.9 million shares of New Common Stock issued to former holders of the Senior Secured Notes and Unsecured Notes (valued at $29.31 per share)	$ 19
Fair value of warrants issued to holders of the Unsecured Notes	88,382
Additional paid-in capital	739,023
Total Successor Company equity issued on Emergence Date	$ 827,424
Warrants
Fair Value Assumptions and Methodology for Assets and Liabilities [Abstract]
Expected volatility rate	59.26%
Risk free interest rate	1.36%
Term	6 years
New Common Stock
Debtor Reorganization Adjustments, Equity [Abstract]
Additional paid-in capital	$ 575,144
New Convertible Notes
Debtor Reorganization Adjustments, Equity [Abstract]
Additional paid-in capital	$ 163,879
Series A Warrants | Warrants
Fair Value Assumptions and Methodology for Assets and Liabilities [Abstract]
Exercise price per share | $ / shares	$ 41.34
Series B Warrants | Warrants
Fair Value Assumptions and Methodology for Assets and Liabilities [Abstract]
Exercise price per share | $ / shares	$ 42.03
Convertible Debt | New Convertible Notes
Fair Value Assumptions and Methodology for Assets and Liabilities [Abstract]
Expected volatility rate	56.06%
Risk free interest rate	1.08%
Term	4 years
Recovery rate	15.00%
Hazard rate	12.41%
Drop on default (percent)	100.00%
Fair value of debt	$ 445,700
Face amount of debt instrument	$ 281,800

Fresh Start Accounting - Fresh

Fresh Start Accounting - Fresh Start Adjustments (Details) $ in Thousands	Oct. 02, 2016USD ($)
Successor
Fresh-Start Adjustment [Line Items]
Accumulated deficit	$ 0

Fresh Start Accounting - Reor58

Fresh Start Accounting - Reorganization Items (Details) - Predecessor - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Reorganization Items [Line Items]
Unamortized long-term debt	$ 3,546,847
Litigation claims	(20,478)
Rejections and cures of executory contracts	(16,038)
Ad valorem and franchise taxes	(3,494)
Legal and professional fees and expenses	(44,920)
Write off of director and officer insurance policy	(7,533)
Gain on accounts payable settlements	84,228
Loss on mortgage	(8,153)
Gain on preferred stock dividends	37,893
Fresh start valuation adjustments	(28,549)
Fair value of equity issued	(827,424)
Principal value of New Convertible Notes issued	(281,780)
Gain on reorganization items, net	$ 2,430,599	$ 0	$ 0

Summary of Significant Accoun59

Summary of Significant Accounting Policies - Narrative (Details) - USD ($)	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014	Apr. 20, 2016	Mar. 11, 2016	Jun. 30, 2015
Senior credit facility
Significant Accounting Policies [Line Items]
Line of credit facility, current borrowing capacity					$ 500,000,000	$ 340,000,000
Successor
Significant Accounting Policies [Line Items]
Allowance for doubtful accounts		$ 0
Capitalized costs	$ 38,062,000
Maximum reserves sold from cost center not expected to result in significant alteration (less than)	25.00%
Natural gas balancing liability	$ 1,700,000
Successor | Internal Costs
Significant Accounting Policies [Line Items]
Capitalized costs	$ 4,000,000
Successor | Buildings | Minimum
Significant Accounting Policies [Line Items]
Property, plant and equipment, useful life	10 years
Successor | Buildings | Maximum
Significant Accounting Policies [Line Items]
Property, plant and equipment, useful life	39 years
Successor | Equipment | Minimum
Significant Accounting Policies [Line Items]
Property, plant and equipment, useful life	2 years
Successor | Equipment | Maximum
Significant Accounting Policies [Line Items]
Property, plant and equipment, useful life	30 years
Successor | Secured Debt | 8.75% Senior Secured Notes due 2020
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate	0.00%
Successor | Convertible Debt | 8.125% Convertible Senior Notes due 2022
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate	0.00%
Successor | Convertible Debt | 7.5% Convertible Senior Notes due 2023
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate	0.00%
Successor | Oil, natural gas and NGL revenues
Significant Accounting Policies [Line Items]
Transportation costs	$ 7,400,000
Predecessor
Significant Accounting Policies [Line Items]
Capitalized costs		156,954,000	$ 846,300,000	$ 1,526,484,000
Natural gas balancing liability			1,500,000
Predecessor | Internal Costs
Significant Accounting Policies [Line Items]
Capitalized costs		22,700,000	45,100,000	55,400,000
Predecessor | Oil And Gas Unproved Properties
Significant Accounting Policies [Line Items]
Interest capitalized during period		$ 2,200,000	10,800,000	14,700,000
Predecessor | Midstream And Corporate Assets
Significant Accounting Policies [Line Items]
Interest capitalized during period			$ 3,300,000	5,000,000
Predecessor | 8.125% Convertible Senior Notes due 2022
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate			8.125%
Predecessor | 7.5% Convertible Senior Notes due 2023
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate			7.50%
Predecessor | Secured Debt | 8.75% Senior Secured Notes due 2020
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate		8.75%	8.75%				8.75%
Predecessor | Convertible Debt | 8.125% Convertible Senior Notes due 2022
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate		8.125%	8.125%
Predecessor | Convertible Debt | 7.5% Convertible Senior Notes due 2023
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate		7.50%	7.50%
Predecessor | Production expenses
Significant Accounting Policies [Line Items]
Transportation costs		$ 26,200,000	$ 45,300,000	$ 35,600,000

Summary of Significant Accoun60

Summary of Significant Accounting Policies - Concentration Risk (Details) - USD ($) $ in Thousands	Oct. 01, 2016	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Concentration Risk [Line Items]
Sales		$ 98,456
Successor | Plains Marketing, L.P.
Concentration Risk [Line Items]
Sales		$ 32,022
Percentage of revenue		32.50%
Successor | Targa Pipeline Mid-Continent West OK LLC
Concentration Risk [Line Items]
Sales		$ 35,845
Percentage of revenue		36.40%
Predecessor
Concentration Risk [Line Items]
Sales	$ 0		$ 104,056	$ 99,421	$ 90,332	$ 143,642	$ 180,152	$ 229,607	$ 215,308	$ 293,809	$ 768,709	$ 1,558,758
Predecessor | Plains Marketing, L.P.
Concentration Risk [Line Items]
Sales										$ 110,370	$ 318,018	$ 597,117
Percentage of revenue										37.60%	41.40%	38.30%
Predecessor | Targa Pipeline Mid-Continent West OK LLC
Concentration Risk [Line Items]
Sales										$ 108,238	$ 231,649	$ 333,027
Percentage of revenue										36.80%	30.10%	21.40%

Summary of Significant Accoun61

Summary of Significant Accounting Policies - Recent Accounting Standards (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Oct. 02, 2016	Jan. 01, 2016	Dec. 31, 2015
Adjustment for Early Adoption
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cash collateral	$ 52,800	$ 52,800
Predecessor
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Assets				$ 2,922,027
Noncontrolling interest				510,184
Retained earnings				(6,992,697)
Predecessor | ASU 2015-02
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Assets			$ (243,400)
Noncontrolling interest			(510,200)
Accounts payable			9,700
Retained earnings			$ 257,100
Predecessor | Other Assets | ASU 2015-03
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs				(69,100)
Predecessor | Current maturities of long-term debt | ASU 2015-03
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs				$ (69,100)

Supplemental Cash Flow Inform62

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Supplemental Disclosure of Cash Flow Information
Cash paid for reorganization items	$ 0
Cash paid for interest, net of amounts capitalized	(1,183)
Cash (paid) received for income taxes	0
Supplemental Disclosure of Noncash Investing and Financing Activities
Cumulative effect of adoption of ASU 2015-02	0
Property, plant and equipment transferred in settlement of contract	0
Change in accrued capital expenditures	10,630
Equity issued for debt	(13,001)
Preferred stock dividends paid in common stock	0
Long-term debt issued, including derivative and net of discount, for asset acquisition and termination of gathering agreement	$ 0
Predecessor
Supplemental Disclosure of Cash Flow Information
Cash paid for reorganization items		$ (55,606)	$ 0	$ 0
Cash paid for interest, net of amounts capitalized		(104,609)	(296,386)	(235,793)
Cash (paid) received for income taxes		(28)	(88)	1,928
Supplemental Disclosure of Noncash Investing and Financing Activities
Cumulative effect of adoption of ASU 2015-02		(247,566)	0	0
Property, plant and equipment transferred in settlement of contract		215,635	0	0
Change in accrued capital expenditures		25,045	177,586	(55,557)
Equity issued for debt		(4,409)	(63,299)	0
Preferred stock dividends paid in common stock		0	(16,188)	0
Long-term debt issued, including derivative and net of discount, for asset acquisition and termination of gathering agreement		$ 0	$ (50,310)	$ 0

Acquisitions and Divestitures -

Acquisitions and Divestitures - Acquisitions (Details) - Predecessor $ in Thousands	1 Months Ended		3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2015USD ($)awell	Oct. 31, 2015USD ($)mi	Mar. 31, 2016USD ($)	Oct. 01, 2016USD ($)	Dec. 31, 2015USD ($)awell	Dec. 31, 2014USD ($)
Business Acquisition [Line Items]
Payments to acquire oil and gas property and equipment				$ 1,328	$ 216,943	$ 18,384
Loss on termination of the gathering contract			$ 89,100	$ 90,184	$ 50,976	$ 0
Pinon Gathering Company LLC
Business Acquisition [Line Items]
Payments to acquire oil and gas property and equipment		$ 48,000
Principal amount of debt issued related to acquisition		$ 78,000
Number of miles of gathering lines acquired | mi		370
Fair value of consideration paid for acquisition		$ 98,300
Loss on termination of the gathering contract		51,000
Rockies Properties | North Park Basin, Jackson County, Colorado
Business Acquisition [Line Items]
Payments to acquire oil and gas property and equipment	$ 191,100
Number acres acquired | a	135,000				135,000
Proceeds from sale of oil and natural gas properties	$ 3,100
Number of wells acquired | well	16				16
Oil and Gas Properties | Pinon Gathering Company LLC
Business Acquisition [Line Items]
Fair value of assets acquired		$ 47,300
Senior Notes | 8.75% Senior Notes due 2020
Business Acquisition [Line Items]
Long-term debt, fixed interest rate	8.75%			8.75%	8.75%

Acquisitions and Divestitures64

Acquisitions and Divestitures - Divestitures (Details) - Predecessor - USD ($)	Oct. 01, 2016	Jan. 21, 2016	Feb. 25, 2014	Feb. 25, 2014	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Payment of certain contract cures and other												$ 11,000,000	$ 24,889,000	$ 0
Loss on termination of the gathering contract							$ 89,100,000					90,184,000	50,976,000	0
Revisions in estimated cash flows												0	44,060,000	(5,848,000)
Revenues	$ 0				$ 104,056,000	$ 99,421,000	$ 90,332,000	$ 143,642,000	$ 180,152,000	$ 229,607,000	$ 215,308,000	293,809,000	768,709,000	1,558,758,000
Expenses												$ 1,200,012,000	$ 5,411,387,000	$ 968,534,000
WTO Properties | Disposal Group, Disposed of by Means Other than Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Payment of certain contract cures and other		$ 11,000,000
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]
Proceeds from sale of oil and natural gas properties			$ 702,600,000
Loss on sale of oil and gas property			$ 0
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	$ 9,400,000
Restricted deposits previously held in escrow, cash received											$ 12,000,000
Revenues				90,900,000
Expenses				63,700,000
Asset Retirement Obligations | 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]
Asset retirement obligations assumed			$ 366,000,000	$ 366,000,000
Treating Agreement | WTO Properties
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revisions in estimated cash flows		$ (34,100,000)
Treating Agreement | WTO Properties | Disposal Group, Disposed of by Means Other than Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contract agreement, term		30 years
Cumulative shortfall accrued		$ 111,900,000
Loss on termination of the gathering contract		$ 89,100,000

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - Predecessor - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Oct. 01, 2016	Dec. 31, 2015
Level 2 | Senior Notes | 8.75% Senior Notes due 2020
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Write off of derivative holder conversion feature to reorganization items	$ 2,500
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
Long-term Debt Holder Conversion Feature
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Write off of derivative holder conversion feature to reorganization items	$ 7,281	$ 0

Fair Value Measurements - Signi

Fair Value Measurements - Significant Unobservable Inputs - Long Term Debt Conversion Feature (Details) - Debt holder conversion feature - Level 3 $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Fair value	$ 29,355
Minimum
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Hazard rate	114.00%
Maximum
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Hazard rate	135.20%
Weighted Average
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, 2016	Dec. 31, 2015
Successor
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative assets	$ 0
Derivative Liabilities	29,714
Successor | Recurring Measurement Basis
Fair Value Assets And Liabilities Measured On Recurring Basis
Investments	7,541
Assets	7,541
Derivative Liabilities, Netting	0
Derivative Liabilities at Fair Value	29,714
Successor | Recurring Measurement Basis | Commodity derivative contracts
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Liabilities, Netting	0
Derivative Liabilities at Fair Value	29,714
Successor | Recurring Measurement Basis | Level 1
Fair Value Assets And Liabilities Measured On Recurring Basis
Investments	7,541
Assets	7,541
Derivative Liabilities	0
Successor | Recurring Measurement Basis | Level 1 | Commodity derivative contracts
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Liabilities	0
Successor | Recurring Measurement Basis | Level 2
Fair Value Assets And Liabilities Measured On Recurring Basis
Investments	0
Assets	0
Derivative Liabilities	29,714
Successor | Recurring Measurement Basis | Level 2 | Commodity derivative contracts
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Liabilities	29,714
Successor | Recurring Measurement Basis | Level 3
Fair Value Assets And Liabilities Measured On Recurring Basis
Investments	0
Assets	0
Derivative Liabilities	0
Successor | Recurring Measurement Basis | Level 3 | Commodity derivative contracts
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Liabilities	$ 0
Predecessor
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative assets		$ 85,524
Derivative Liabilities		1,748
Predecessor | Recurring Measurement Basis
Fair Value Assets And Liabilities Measured On Recurring Basis
Investments		10,106
Assets		94,455
Derivative Assets, Netting		(1,175)
Derivative Liabilities, Netting		(1,175)
Derivative Liabilities at Fair Value		32,869
Predecessor | Recurring Measurement Basis | Commodity derivative contracts
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Assets, Netting		(1,175)
Derivative Assets at Fair Value		84,349
Derivative Liabilities, Netting		(1,175)
Derivative Liabilities at Fair Value		573
Predecessor | Recurring Measurement Basis | Debt holder conversion feature
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Liabilities, Netting		0
Derivative Liabilities at Fair Value		29,355
Predecessor | Recurring Measurement Basis | Mandatory prepayment feature - PGC Senior Secured Notes
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Liabilities, Netting		0
Derivative Liabilities at Fair Value		2,941
Predecessor | Recurring Measurement Basis | Level 1
Fair Value Assets And Liabilities Measured On Recurring Basis
Investments		10,106
Assets		10,106
Derivative Liabilities		0
Predecessor | Recurring Measurement Basis | Level 1 | Commodity derivative contracts
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative assets		0
Derivative Liabilities		0
Predecessor | Recurring Measurement Basis | Level 1 | Debt holder conversion feature
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Liabilities		0
Predecessor | Recurring Measurement Basis | Level 1 | Mandatory prepayment feature - PGC Senior Secured Notes
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Liabilities		0
Predecessor | Recurring Measurement Basis | Level 2
Fair Value Assets And Liabilities Measured On Recurring Basis
Investments		0
Assets		85,524
Derivative Liabilities		2,941
Predecessor | Recurring Measurement Basis | Level 2 | Commodity derivative contracts
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative assets		85,524
Derivative Liabilities		0
Predecessor | Recurring Measurement Basis | Level 2 | Debt holder conversion feature
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Liabilities		0
Predecessor | Recurring Measurement Basis | Level 2 | Mandatory prepayment feature - PGC Senior Secured Notes
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Liabilities		2,941
Predecessor | Recurring Measurement Basis | Level 3
Fair Value Assets And Liabilities Measured On Recurring Basis
Investments		0
Assets		0
Derivative Liabilities		31,103
Predecessor | Recurring Measurement Basis | Level 3 | Commodity derivative contracts
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative assets		0
Derivative Liabilities		1,748
Predecessor | Recurring Measurement Basis | Level 3 | Debt holder conversion feature
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Liabilities		29,355
Predecessor | Recurring Measurement Basis | Level 3 | Mandatory prepayment feature - PGC Senior Secured Notes
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Liabilities		$ 0

Fair Value Measurements - Recon

Fair Value Measurements - Reconciliation of Fair Value Measurements for Long-Term Debt Holder Conversion Feature (Details) - Predecessor - Debt holder conversion feature - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Oct. 01, 2016	Dec. 31, 2015
Level 3 Fair Value Measurements - Long-Term Debt Holder Conversion Feature
Beginning balance	$ 29,355	$ 0
Issuances	0	31,200
(Loss) gain on derivative holder conversion feature	(880)	10,198
Conversions	(21,194)	(12,043)
Write off of derivative holder conversion feature to reorganization items	(7,281)	0
Ending balance	$ 0	$ 29,355

Fair Value Measurements - Estim

Fair Value Measurements - Estimated Fair Value and Carrying Value of Senior Notes (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Jun. 30, 2015
Convertible Debt | New Convertible Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Value	$ 268,780
Successor
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Value	305,308
Successor | Secured Debt | New Building Note
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value		$ 36,600
Carrying Value	$ 36,528
Successor | Secured Debt | 8.75% Senior Secured Notes due 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Carrying Value	$ 0
Successor | Senior Notes | 8.75% Senior Notes due 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Carrying Value	$ 0
Successor | Senior Notes | 7.5% Senior Notes due 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Carrying Value	$ 0
Successor | Senior Notes | 8.125% Senior Notes due 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Carrying Value	$ 0
Successor | Senior Notes | 7.5% Senior Notes due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Carrying Value	$ 0
Successor | Convertible Debt | New Convertible Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value		$ 445,700
Carrying Value	$ 268,780
Successor | Convertible Debt | 8.125% Convertible Senior Notes due 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Carrying Value	$ 0
Successor | Convertible Debt | 7.5% Convertible Senior Notes due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Carrying Value	$ 0
Successor | Level 2 | Secured Debt | New Building Note
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value	$ 40,608
Successor | Level 2 | Secured Debt | 8.75% Senior Secured Notes due 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Fair Value	$ 0
Successor | Level 2 | Senior Notes | 8.75% Senior Notes due 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Fair Value	$ 0
Successor | Level 2 | Senior Notes | 7.5% Senior Notes due 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Fair Value	$ 0
Successor | Level 2 | Senior Notes | 8.125% Senior Notes due 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Fair Value	$ 0
Successor | Level 2 | Senior Notes | 7.5% Senior Notes due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Fair Value	$ 0
Successor | Level 2 | Convertible Debt | New Convertible Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value	$ 334,800
Successor | Level 2 | Convertible Debt | 8.125% Convertible Senior Notes due 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Fair Value	$ 0
Successor | Level 2 | Convertible Debt | 7.5% Convertible Senior Notes due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate	0.00%
Fair Value	$ 0
Predecessor
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Value			$ 3,562,378
Predecessor | 8.125% Convertible Senior Notes due 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate			8.125%
Predecessor | 7.5% Convertible Senior Notes due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate			7.50%
Predecessor | Secured Debt | New Building Note
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Value			$ 0
Predecessor | Secured Debt | 8.75% Senior Secured Notes due 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate		8.75%	8.75%	8.75%
Carrying Value			$ 1,265,814
Predecessor | Senior Notes | 8.75% Senior Notes due 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate		8.75%	8.75%
Carrying Value			$ 389,232
Predecessor | Senior Notes | 7.5% Senior Notes due 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate		7.50%	7.50%
Carrying Value			$ 751,087
Predecessor | Senior Notes | 8.125% Senior Notes due 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate		8.125%	8.125%
Carrying Value			$ 518,693
Predecessor | Senior Notes | 7.5% Senior Notes due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate		7.50%	7.50%
Carrying Value			$ 534,869
Predecessor | Convertible Debt | New Convertible Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Value			$ 0
Predecessor | Convertible Debt | 8.125% Convertible Senior Notes due 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate		8.125%	8.125%
Carrying Value			$ 78,290
Predecessor | Convertible Debt | 7.5% Convertible Senior Notes due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate		7.50%	7.50%
Carrying Value			$ 24,393
Predecessor | Level 2 | Secured Debt | New Building Note
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value			$ 0
Predecessor | Level 2 | Secured Debt | 8.75% Senior Secured Notes due 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate			8.75%
Fair Value			$ 403,098
Predecessor | Level 2 | Senior Notes | 8.75% Senior Notes due 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate			8.75%
Fair Value			$ 39,740
Predecessor | Level 2 | Senior Notes | 7.5% Senior Notes due 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate			7.50%
Fair Value			$ 79,812
Predecessor | Level 2 | Senior Notes | 8.125% Senior Notes due 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate			8.125%
Fair Value			$ 57,749
Predecessor | Level 2 | Senior Notes | 7.5% Senior Notes due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate			7.50%
Fair Value			$ 58,799
Predecessor | Level 2 | Convertible Debt | New Convertible Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value			$ 0
Predecessor | Level 2 | Convertible Debt | 8.125% Convertible Senior Notes due 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate			8.125%
Fair Value			$ 44,199
Predecessor | Level 2 | Convertible Debt | 7.5% Convertible Senior Notes due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fixed interest rate			7.50%
Fair Value			$ 15,125

Accounts Receivable - Summary o

Accounts Receivable - Summary of Accounts Receivable (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Successor
Accounts, Notes, Loans and Financing Receivable [Line Items]
Oil, natural gas and NGL sales	$ 42,631
Joint interest billing	17,338
Oil and natural gas services	736
Other	14,272
Total accounts receivable	74,977
Less: allowance for doubtful accounts	(880)	$ 0
Total accounts receivable, net	$ 74,097
Predecessor
Accounts, Notes, Loans and Financing Receivable [Line Items]
Oil, natural gas and NGL sales			$ 61,140
Joint interest billing			60,403
Oil and natural gas services			2,417
Other			8,274
Total accounts receivable			132,234
Less: allowance for doubtful accounts		$ 0	(4,847)	$ (7,083)	$ (11,061)
Total accounts receivable, net			$ 127,387

Accounts Receivable - Balance a

Accounts Receivable - Balance and Activity in Allowance for Doubtful Accounts (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	$ 0
Provision for doubtful accounts	880
Deductions	0
Impact of fresh start accounting	0
Ending balance	880	$ 0
Predecessor
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	$ 0	4,847	$ 7,083	$ 11,061
Provision for doubtful accounts		16,695	1,320	818
Deductions		(751)	(3,556)	(4,796)
Impact of fresh start accounting		(20,791)	0	0
Ending balance		$ 0	$ 4,847	$ 7,083

Property, Plant and Equipment72

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Oil and natural gas properties, using full cost method of accounting
Proved	$ 840,201
Unproved	74,937
Total oil and natural gas properties	915,138
Less: accumulated depreciation, depletion and impairment	(353,030)
Net oil and natural gas properties capitalized costs	562,108
Land	5,100
Non-oil and natural gas equipment	166,010
Buildings and structures	88,603
Total	259,713
Less accumulated depreciation and amortization	(3,889)
Other property, plant and equipment, net	255,824
Total property, plant and equipment, net	$ 817,932
Predecessor
Oil and natural gas properties, using full cost method of accounting
Proved		$ 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
Non-oil and natural gas equipment		373,687
Buildings and structures		227,673
Total		615,620
Less accumulated depreciation and amortization		(123,860)
Other property, plant and equipment, net		491,760
Total property, plant and equipment, net		2,234,702
Predecessor | Oil and gas proved properties
Oil and natural gas properties, using full cost method of accounting
Cumulative capitalized interest		48,900
Predecessor | Non-oil and natural gas equipment
Oil and natural gas properties, using full cost method of accounting
Cumulative capitalized interest		4,300
Predecessor | Buildings
Oil and natural gas properties, using full cost method of accounting
Cumulative capitalized interest		$ 20,400

Property, Plant and Equipment -

Property, Plant and Equipment - Narrative (Details)	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016USD ($)$ / Boe	Oct. 01, 2016USD ($)$ / Boe	Dec. 31, 2015USD ($)$ / Boe	Dec. 31, 2014USD ($)well$ / Boe	Jun. 30, 2015USD ($)	May 31, 2015USD ($)well
Predecessor
Property, Plant and Equipment [Line Items]
Cumulative full cost ceiling limitation impairment charges			$ 8,200,000,000
Full cost ceiling impairments		$ 657,392,000	$ 4,473,787,000	$ 164,779,000
Average depreciation and depletion rate (usd per Boe) | $ / Boe		5.76	10.67	15
Predecessor | Repsol
Property, Plant and Equipment [Line Items]
Drilling carry received or billed				$ 205,600,000
Predecessor | Repsol
Property, Plant and Equipment [Line Items]
Minimum net wells | well				484
Net wells | well						453
Costs incurred toward satisfaction of obligation		$ 6,200,000	$ 16,100,000
Predecessor | 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				$ 75,000,000		$ 31,000,000
Predecessor | Drilling and Oil Field Services
Property, Plant and Equipment [Line Items]
Other operating expenses			3,500,000
Predecessor | Drilling And Oil Field Services Assets
Property, Plant and Equipment [Line Items]
Assets held for sale			$ 16,000,000		$ 20,000,000
Successor
Property, Plant and Equipment [Line Items]
Full cost ceiling impairments	$ 319,087,000
Average depreciation and depletion rate (usd per Boe) | $ / Boe	7.82
Expected completion of evaluation activities on majority of unproved properties	10 years
Successor | Repsol
Property, Plant and Equipment [Line Items]
Bankruptcy claims settled	$ 1,200,000
Successor | Drilling And Oil Field Services Assets
Property, Plant and Equipment [Line Items]
Assets held for sale	$ 0

Property, Plant and Equipment74

Property, Plant and Equipment - Capitalized Costs of Unproved Properties Excluded from Amortization (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Successor
Property, Plant and Equipment [Line Items]
Property acquisition, cumulative	$ 71,171
Property acquisition	7,390
Exploration, cumulative	20,459
Exploration	2,123
Total costs incurred, cumulative	91,630
Total costs incurred	9,513
Pipe inventory costs, cumulative	16,700
Pipe inventory costs, period costs	$ 2,100
Predecessor
Property, Plant and Equipment [Line Items]
Property acquisition, cumulative				$ 10,052
Property acquisition		$ 18,959	$ 34,770
Exploration, cumulative				3,080
Exploration		10,578	4,678
Total costs incurred, cumulative				$ 13,132
Total costs incurred		29,537	39,448
Pipe inventory costs, period costs		$ 9,600	$ 5,000

Impairment - Narrative (Details

Impairment - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended								9 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Full cost pool ceiling impairments	$ 319,087
Asset impairment charges	319,087
Other property, plant and equipment, net	255,824
Successor | Drilling assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges	0
Successor | Electric transmission assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges	0
Successor | Midstream assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges	0
Successor | Other
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges	$ 0
Predecessor
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Full cost pool ceiling impairments									$ 657,392	$ 4,473,787	$ 164,779
Asset impairment charges		$ 354,500	$ 253,600	$ 110,100	$ 886,800	$ 1,100,000	$ 1,500,000	$ 1,100,000	718,194	4,534,689	192,768
Other property, plant and equipment, net					$ 491,760					491,760
Predecessor | Drilling assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges									3,511	37,646	27,428
Predecessor | Electric transmission assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges									55,600	0	0
Predecessor | Midstream assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges									1,691	7,148	561
Predecessor | Other
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges									$ 0	16,108	0
Predecessor | Permian Region | Drilling assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges											$ 24,300
Predecessor | Oklahoma City, Oklahoma | Other
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges										$ 15,400

Accounts Payable and Accrued 76

Accounts Payable and Accrued Expenses (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Successor
Schedule of Accounts Payable and Accrued Liabilities [Line Items]
Accounts payable and other accrued expenses	$ 65,408
Accrued interest	648
Production payable	16,011
Payroll and benefits	33,606
Convertible perpetual preferred stock dividends	0
Drilling advances	844
Related party	0
Total accounts payable and accrued expenses	$ 116,517
Predecessor
Schedule of Accounts Payable and Accrued Liabilities [Line Items]
Accounts payable and other accrued expenses		$ 231,697
Accrued interest		73,320
Production payable		55,260
Payroll and benefits		42,728
Convertible perpetual preferred stock dividends		21,572
Drilling advances		2,295
Related party		1,545
Total accounts payable and accrued expenses		$ 428,417

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Jun. 30, 2015
Convertible Debt | New Convertible Notes
Debt Instrument [Line Items]
Total debt	$ 268,780
Successor
Debt Instrument [Line Items]
Total debt	305,308
Less: current maturities of long-term debt	0
Long-term debt	305,308
Successor | Revolving Credit Facility | New First Lien Exit Facility
Debt Instrument [Line Items]
Total debt	0
Successor | Senior credit facility
Debt Instrument [Line Items]
Total debt	0
Successor | Secured Debt | New Building Note
Debt Instrument [Line Items]
Total debt	$ 36,528
Successor | Secured Debt | 8.75% Senior Secured Notes due 2020
Debt Instrument [Line Items]
Long-term debt, fixed interest rate	0.00%
Total debt	$ 0
Successor | Senior Notes | 8.75% Senior Notes due 2020
Debt Instrument [Line Items]
Long-term debt, fixed interest rate	0.00%
Total debt	$ 0
Successor | Senior Notes | 7.5% Senior Notes due 2021
Debt Instrument [Line Items]
Long-term debt, fixed interest rate	0.00%
Total debt	$ 0
Successor | Senior Notes | 8.125% Senior Notes due 2022
Debt Instrument [Line Items]
Long-term debt, fixed interest rate	0.00%
Total debt	$ 0
Successor | Senior Notes | 7.5% Senior Notes due 2023
Debt Instrument [Line Items]
Long-term debt, fixed interest rate	0.00%
Total debt	$ 0
Successor | Convertible Debt | New Convertible Notes
Debt Instrument [Line Items]
Total debt	$ 268,780
Successor | Convertible Debt | 8.125% Convertible Senior Notes due 2022
Debt Instrument [Line Items]
Long-term debt, fixed interest rate	0.00%
Total debt	$ 0
Successor | Convertible Debt | 7.5% Convertible Senior Notes due 2023
Debt Instrument [Line Items]
Long-term debt, fixed interest rate	0.00%
Total debt	$ 0
Predecessor
Debt Instrument [Line Items]
Total debt			$ 3,562,378
Less: current maturities of long-term debt			0
Long-term debt			$ 3,562,378
Predecessor | 8.125% Convertible Senior Notes due 2022
Debt Instrument [Line Items]
Long-term debt, fixed interest rate			8.125%
Predecessor | 7.5% Convertible Senior Notes due 2023
Debt Instrument [Line Items]
Long-term debt, fixed interest rate			7.50%
Predecessor | Revolving Credit Facility | New First Lien Exit Facility
Debt Instrument [Line Items]
Total debt			$ 0
Predecessor | Senior credit facility
Debt Instrument [Line Items]
Total debt			0
Predecessor | Secured Debt | New Building Note
Debt Instrument [Line Items]
Total debt			$ 0
Predecessor | Secured Debt | 8.75% Senior Secured Notes due 2020
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		8.75%	8.75%	8.75%
Total debt			$ 1,265,814
Predecessor | Senior Notes | 8.75% Senior Notes due 2020
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		8.75%	8.75%
Total debt			$ 389,232
Predecessor | Senior Notes | 7.5% Senior Notes due 2021
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		7.50%	7.50%
Total debt			$ 751,087
Predecessor | Senior Notes | 8.125% Senior Notes due 2022
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		8.125%	8.125%
Total debt			$ 518,693
Predecessor | Senior Notes | 7.5% Senior Notes due 2023
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		7.50%	7.50%
Total debt			$ 534,869
Predecessor | Convertible Debt | New Convertible Notes
Debt Instrument [Line Items]
Total debt			$ 0
Predecessor | Convertible Debt | 8.125% Convertible Senior Notes due 2022
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		8.125%	8.125%
Total debt			$ 78,290
Predecessor | Convertible Debt | 7.5% Convertible Senior Notes due 2023
Debt Instrument [Line Items]
Long-term debt, fixed interest rate		7.50%	7.50%
Total debt			$ 24,393

Long-Term Debt - Narrative (Det

Long-Term Debt - Narrative (Details) $ / shares in Units, shares in Millions	Oct. 01, 2016USD ($)shares$ / shares	May 11, 2016USD ($)	Jun. 30, 2015USD ($)	Dec. 31, 2016USD ($)shares	Mar. 31, 2016USD ($)	Oct. 01, 2016USD ($)shares	Dec. 31, 2015USD ($)shares	Dec. 31, 2014USD ($)	Apr. 20, 2016USD ($)	Mar. 11, 2016USD ($)	Oct. 31, 2015USD ($)	Oct. 16, 2015USD ($)
Senior credit facility
Debt Instrument [Line Items]
Letters of credit outstanding				$ 8,600,000
Line of credit facility, current borrowing capacity									$ 500,000,000	$ 340,000,000
Convertible Debt | New Convertible Notes
Debt Instrument [Line Items]
Face value of long-term debt				268,780,000
Revolving Credit Facility | New First Lien Exit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 425,000,000					$ 425,000,000
Revolving Credit Facility | New First Lien Exit Facility | LIBOR
Debt Instrument [Line Items]
Basis spread on variable rate	4.75%
Variable rate floor	1.00%
Successor
Debt Instrument [Line Items]
Face value of long-term debt				305,308,000
Common stock issued for debt				13,001,000
Repayments of debt				0
Gain on extinguishment of debt				0
Write off of debt issuance costs				0
Long-term debt maturing in 2020				268,800,000
Long-term debt maturing in 2021				35,000,000
Successor | Senior credit facility
Debt Instrument [Line Items]
Face value of long-term debt				0
Successor | Secured Debt | New Building Note
Debt Instrument [Line Items]
Face value of long-term debt				$ 36,528,000
Face amount of debt instrument	$ 35,000,000					35,000,000
Fair value of debt	$ 36,600,000					$ 36,600,000
Effective interest rate				10.90%
Interest payment period number of days after refinancing	90 days
Proceeds from issuance of debt	$ 26,800,000
Term	46 months
Successor | Secured Debt | 8.75% Senior Secured Notes due 2020
Debt Instrument [Line Items]
Face value of long-term debt				$ 0
Long-term debt, fixed interest rate				0.00%
Successor | Secured Debt | October 5, 2016 through October 4, 2017 | New Building Note
Debt Instrument [Line Items]
Annual interest rate	6.00%					6.00%
Successor | Secured Debt | October 5, 2017 through October 4, 2018 | New Building Note
Debt Instrument [Line Items]
Annual interest rate	8.00%					8.00%
Successor | Secured Debt | October 5, 2018 and thereafter | New Building Note
Debt Instrument [Line Items]
Annual interest rate	10.00%					10.00%
Successor | Senior Notes | 8.75% Senior Notes due 2020
Debt Instrument [Line Items]
Face value of long-term debt				$ 0
Long-term debt, fixed interest rate				0.00%
Successor | Convertible Debt | New Convertible Notes
Debt Instrument [Line Items]
Face value of long-term debt				$ 268,780,000
Face amount of debt instrument	$ 281,800,000					$ 281,800,000
Fair value of debt	445,700,000					445,700,000
Premium on debt instrument	$ 163,900,000					$ 163,900,000
Call provision ratio	0.783478					0.783478
Conversion ratio	0.05330841
Number of shares issuable under convertible securities | shares	15
Proceeds from stock issuance trigger mandatory conversion	$ 100,000,000
Initial conversion price threshold (usd per share) | $ / shares	$ 34.16
Conversion written notice period	30 days
Threshold consecutive trading days	30 days
Convertible debt, threshold percentage of stock price trigger	50.00%
Common stock issued for debt				$ 13,000,000
Common stock issued for debt (in shares) | shares				0.7
Redemption price percentage	100.00%
Principal required to be secured	$ 100,000,000					$ 100,000,000
Successor | Convertible Debt | 8.125% Convertible Senior Notes due 2022
Debt Instrument [Line Items]
Face value of long-term debt				$ 0
Long-term debt, fixed interest rate				0.00%
Successor | Convertible Debt | 7.5% Convertible Senior Notes due 2023
Debt Instrument [Line Items]
Face value of long-term debt				$ 0
Long-term debt, fixed interest rate				0.00%
Successor | Revolving Credit Facility | New First Lien Exit Facility
Debt Instrument [Line Items]
Face value of long-term debt				$ 0
Maximum borrowing capacity	$ 425,000,000					$ 425,000,000
Amount of proved developed producing reserves pledged as collateral (percentage)	95.00%					95.00%
Minimum collateral amount of proved oil and gas reserves representing the discounted present value of reserves used in borrowing base determination	95.00%					95.00%
Covenant, Proved developed producing asset coverage ratio	1.75					1.75
Minimum consolidated interest coverage ratio	2					2
Successor | Revolving Credit Facility | New First Lien Exit Facility | Maximum
Debt Instrument [Line Items]
Line of credit facility, unused capacity, commitment fee percentage						0.50%
Successor | Revolving Credit Facility | New First Lien Exit Facility | Base Rate
Debt Instrument [Line Items]
Basis spread on variable rate	3.75%
Successor | Revolving Credit Facility | New First Lien Exit Facility | LIBOR
Debt Instrument [Line Items]
Basis spread on variable rate	4.75%
Variable rate floor	1.00%
Successor | Revolving Credit Facility | On or prior to December 31, 2018 | New First Lien Exit Facility
Debt Instrument [Line Items]
Maximum consolidated net leverage ratio	3.50					3.50
Successor | Revolving Credit Facility | On or After March 31, 2019 | New First Lien Exit Facility
Debt Instrument [Line Items]
Maximum consolidated net leverage ratio	3					3
Predecessor
Debt Instrument [Line Items]
Face value of long-term debt							$ 3,562,378,000
Unamortized discount (premium) and debt issuance costs, net							342,600,000
Embedded derivative, fair value							32,300,000
Net unamortized discount (premium) and debt issuance costs written off						$ 158,600,000
Embedded derivative written off						9,800,000
Common stock issued for debt						$ 4,409,000	$ 63,299,000	$ 0
Common stock issued for debt (in shares) | shares						84.4	92.8
Repayments of debt						$ 33,874,000	$ 0	0
Aggregate cash payments for accrued interest and early conversion of debt						33,500,000	30,500,000
Gain on extinguishment of debt					$ 41,300,000	41,179,000	641,131,000	0
Write off of debt issuance costs						0	7,108,000	$ 0
Predecessor | Conversion of Senior Notes to Common Stock
Debt Instrument [Line Items]
Gain on extinguishment of debt						41,300,000	6,100,000
Write off of debt issuance costs						4,300,000	$ 5,200,000
Predecessor | 8.125% Convertible Senior Notes due 2022
Debt Instrument [Line Items]
Long-term debt, fixed interest rate							8.125%
Predecessor | 7.5% Convertible Senior Notes due 2023
Debt Instrument [Line Items]
Long-term debt, fixed interest rate							7.50%
Predecessor | Senior credit facility
Debt Instrument [Line Items]
Debt canceled	$ 449,200,000					$ 449,200,000
Face value of long-term debt							$ 0
Minimum collateral amount of proved oil and gas reserves representing the discounted present value of reserves used in borrowing base determination	80.00%					80.00%
Number of days prior to earliest maturity date or mandatory offer of repurchase						91 days
Repayments of debt		$ 40,000,000
Predecessor | Senior credit facility | Base Rate | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate						0.75%
Predecessor | Senior credit facility | Base Rate | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate						1.75%
Predecessor | Senior credit facility | LIBOR | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate						1.75%
Predecessor | Senior credit facility | LIBOR | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate						2.75%
Predecessor | Senior credit facility | Federal Funds
Debt Instrument [Line Items]
Basis spread on variable rate						0.50%
Predecessor | Senior credit facility | One-Month Eurodollar Rate
Debt Instrument [Line Items]
Basis spread on variable rate						1.00%
Predecessor | Senior credit facility | June Amendment
Debt Instrument [Line Items]
Ratio of secured debt to EBITDA, maximum	2					2
Current assets to current liabilities, ratio minimum	1					1
Predecessor | Senior credit facility | August 2015 Amendment
Debt Instrument [Line Items]
Allowed repurchases of outstanding debt												$ 275,000,000
Predecessor | Secured Debt
Debt Instrument [Line Items]
Debt canceled	$ 1,300,000,000					$ 1,300,000,000
Predecessor | Secured Debt | New Building Note
Debt Instrument [Line Items]
Face value of long-term debt							0
Predecessor | Secured Debt | 8.75% Senior Secured Notes due 2020
Debt Instrument [Line Items]
Face value of long-term debt							$ 1,265,814,000
Face amount of debt instrument			$ 1,250,000,000								$ 78,000,000
Long-term debt, fixed interest rate	8.75%		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
Predecessor | Senior Notes
Debt Instrument [Line Items]
Debt canceled	$ 2,200,000,000					$ 2,200,000,000
Predecessor | Senior Notes | 8.75% Senior Notes due 2020
Debt Instrument [Line Items]
Face value of long-term debt							$ 389,232,000
Long-term debt, fixed interest rate	8.75%					8.75%	8.75%
Mandatory prepayment feature, threshold amount of outstanding principal amount of senior notes	$ 100,000,000					$ 100,000,000
Predecessor | Convertible Debt
Debt Instrument [Line Items]
Debt canceled	$ 87,600,000					87,600,000
Debt conversion, original debt, amount						$ 232,100,000	$ 255,300,000
Predecessor | Convertible Debt | New Convertible Notes
Debt Instrument [Line Items]
Face value of long-term debt							0
Predecessor | Convertible Debt | 8.125% Convertible Senior Notes due 2022
Debt Instrument [Line Items]
Face value of long-term debt							$ 78,290,000
Long-term debt, fixed interest rate	8.125%					8.125%	8.125%
Debt conversion, original debt, amount						$ 200,500,000	$ 186,600,000
Debt conversion, original debt aggregate principal, net of discount and including holder's conversion feature						$ 67,400,000	54,400,000
Predecessor | Convertible Debt | 7.5% Convertible Senior Notes due 2023
Debt Instrument [Line Items]
Face value of long-term debt							$ 24,393,000
Long-term debt, fixed interest rate	7.50%					7.50%	7.50%
Debt conversion, original debt, amount						$ 31,600,000	$ 68,700,000
Debt conversion, original debt aggregate principal, net of discount and including holder's conversion feature						$ 10,400,000	19,300,000
Predecessor | Revolving Credit Facility | New First Lien Exit Facility
Debt Instrument [Line Items]
Face value of long-term debt							$ 0

Derivatives - Offsetting Assets

Derivatives - Offsetting Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Successor
ASSETS
Derivative assets, gross amounts	$ 0
Derivative assets, gross amounts offset	0
Derivative assets, amounts net of offset	0
Derivative assets, financial collateral	0
Derivative assets, net amount	0
LIABILITIES
Derivative liabilities, gross amounts	29,714
Derivative liabilities, gross amounts offset	0
Derivative liabilities, amount net of offset	29,714
Derivative liabilities, financial collateral	(29,714)
Derivative liabilities, net amount	0
Successor | Derivative contracts - current
ASSETS
Derivative assets, gross amounts	0
Derivative assets, gross amounts offset	0
Derivative assets, amounts net of offset	0
Derivative assets, financial collateral	0
Derivative assets, net amount	0
Successor | Noncurrent assets
ASSETS
Derivative assets, gross amounts	0
Derivative assets, gross amounts offset	0
Derivative assets, amounts net of offset	0
Derivative assets, financial collateral	0
Derivative assets, net amount	0
Successor | Derivative contracts - current
LIABILITIES
Derivative liabilities, gross amounts	27,538
Derivative liabilities, gross amounts offset	0
Derivative liabilities, amount net of offset	27,538
Derivative liabilities, financial collateral	(27,538)
Derivative liabilities, net amount	0
Successor | Derivative contracts - noncurrent
LIABILITIES
Derivative liabilities, gross amounts	2,176
Derivative liabilities, gross amounts offset	0
Derivative liabilities, amount net of offset	2,176
Derivative liabilities, financial collateral	(2,176)
Derivative liabilities, net amount	$ 0
Predecessor
ASSETS
Derivative assets, gross amounts		$ 85,524
Derivative assets, gross amounts offset		(1,175)
Derivative assets, amounts net of offset		84,349
Derivative assets, financial collateral		0
Derivative assets, net amount		84,349
LIABILITIES
Derivative liabilities, gross amounts		1,748
Derivative liabilities, gross amounts offset		(1,175)
Derivative liabilities, amount net of offset		573
Derivative liabilities, financial collateral		(573)
Derivative liabilities, net amount		0
Predecessor | Derivative contracts - current
ASSETS
Derivative assets, gross amounts		85,524
Derivative assets, gross amounts offset		(1,175)
Derivative assets, amounts net of offset		84,349
Derivative assets, financial collateral		0
Derivative assets, net amount		84,349
Predecessor | Noncurrent assets
ASSETS
Derivative assets, gross amounts		0
Derivative assets, gross amounts offset		0
Derivative assets, amounts net of offset		0
Derivative assets, financial collateral		0
Derivative assets, net amount		0
Predecessor | Derivative contracts - current
LIABILITIES
Derivative liabilities, gross amounts		1,748
Derivative liabilities, gross amounts offset		(1,175)
Derivative liabilities, amount net of offset		573
Derivative liabilities, financial collateral		(573)
Derivative liabilities, net amount		0
Predecessor | Derivative contracts - noncurrent
LIABILITIES
Derivative liabilities, gross amounts		0
Derivative liabilities, gross amounts offset		0
Derivative liabilities, amount net of offset		0
Derivative liabilities, financial collateral		0
Derivative liabilities, net amount		$ 0

Derivatives - Open Commodity De

Derivatives - Open Commodity Derivative Contracts (Details)	12 Months Ended
	Dec. 31, 2016$ / Mcf$ / bblMBblsMcf
Oil Price Swaps, January 2017 - December 2017
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional (Oil in MBbl/Natural Gas in MMcf) | MBbls	3,285
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / bbl	52.24
Oil Price Swaps, January 2018 - December 2018
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional (Oil in MBbl/Natural Gas in MMcf) | MBbls	1,825
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / bbl	55.34
Natural Gas Price Swaps, January 2017 - December 2017
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional (Oil in MBbl/Natural Gas in MMcf) | Mcf	32,850
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / Mcf	3.20
Natural Gas Price Swaps, January 2018 - December 2018
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional (Oil in MBbl/Natural Gas in MMcf) | Mcf	3,650
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / Mcf	3.12

Derivatives - Fair Value of Der

Derivatives - Fair Value of Derivative Contracts (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Successor
Derivatives, Fair Value [Line Items]
Assets	$ 0
Derivative liabilities	(29,714)
Total net derivative contracts	(29,714)
Successor | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Assets	0
Successor | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Derivative liabilities	(27,538)
Successor | Derivative contracts - noncurrent
Derivatives, Fair Value [Line Items]
Derivative liabilities	(2,176)
Successor | Oil price swaps | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Assets	0
Successor | Oil price swaps | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Derivative liabilities	(13,395)
Successor | Oil price swaps | Derivative contracts - noncurrent
Derivatives, Fair Value [Line Items]
Derivative liabilities	(2,105)
Successor | Oil collars—three way | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Assets	0
Successor | Natural gas price swaps | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Derivative liabilities	(14,143)
Successor | Natural gas price swaps | Derivative contracts - noncurrent
Derivatives, Fair Value [Line Items]
Derivative liabilities	(71)
Successor | Natural gas basis swaps | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Derivative liabilities	0
Successor | Debt holder conversion feature | Current maturities of long-term debt
Derivatives, Fair Value [Line Items]
Derivative liabilities	0
Successor | Mandatory prepayment feature - PGC Senior Secured Notes | Current maturities of long-term debt
Derivatives, Fair Value [Line Items]
Derivative liabilities	$ 0
Predecessor
Derivatives, Fair Value [Line Items]
Assets		$ 85,524
Derivative liabilities		(1,748)
Total net derivative contracts		51,480
Predecessor | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Assets		85,524
Predecessor | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Derivative liabilities		(1,748)
Predecessor | Derivative contracts - noncurrent
Derivatives, Fair Value [Line Items]
Derivative liabilities		0
Predecessor | Oil price swaps | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Assets		68,224
Predecessor | Oil price swaps | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Derivative liabilities		0
Predecessor | Oil price swaps | Derivative contracts - noncurrent
Derivatives, Fair Value [Line Items]
Derivative liabilities		0
Predecessor | Oil collars—three way | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Assets		17,300
Predecessor | Natural gas price swaps | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Derivative liabilities		0
Predecessor | Natural gas price swaps | Derivative contracts - noncurrent
Derivatives, Fair Value [Line Items]
Derivative liabilities		0
Predecessor | Natural gas basis swaps | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Derivative liabilities		(1,748)
Predecessor | Debt holder conversion feature | Current maturities of long-term debt
Derivatives, Fair Value [Line Items]
Derivative liabilities		(29,355)
Predecessor | Mandatory prepayment feature - PGC Senior Secured Notes | Current maturities of long-term debt
Derivatives, Fair Value [Line Items]
Derivative liabilities		$ (2,941)

Derivatives - Narrative (Detail

Derivatives - Narrative (Details)	3 Months Ended						9 Months Ended	12 Months Ended
	Dec. 31, 2016USD ($)institution	Jun. 30, 2016USD ($)	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Oct. 01, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Successor
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Loss (gain) on derivative contracts	$ 25,652,000
Cash (receipts) payments on early settlement	$ (7,698,000)
Number of counterparties to open derivative contracts | institution	4
Successor | Commodity Derivatives
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Loss (gain) on derivative contracts	$ 25,700,000
Cash (receipts) payments on settlement	$ (7,700,000)
Successor | Senior Notes | 8.75% Senior Notes due 2020
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Long-term debt, fixed interest rate	0.00%
Predecessor
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Loss (gain) on derivative contracts			$ (14,000,000)	$ (42,200,000)	$ 33,000,000	$ (49,800,000)	$ 4,823,000	$ (73,061,000)	$ (334,011,000)
Cash (receipts) payments on early settlement							(72,608,000)	(327,702,000)	(11,796,000)
Predecessor | Commodity Derivatives
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Loss (gain) on derivative contracts							4,800,000	(73,100,000)	(334,000,000)
Cash (receipts) payments on settlement							$ (72,600,000)	$ (327,700,000)	32,300,000
Cash (receipts) payments on early settlement		$ (17,900,000)							$ (69,900,000)
Predecessor | 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%
Mandatory prepayment feature, threshold amount of outstanding principal amount of senior notes							$ 100,000,000

Asset Retirement Obligations -

Asset Retirement Obligations - Reconciliation of Beginning and Ending Aggregate Carrying Amounts of Asset Retirement Obligations (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Asset Retirement Obligation, Roll Forward Analysis
Beginning balance	$ 92,413
Liability incurred upon acquiring and drilling wells	121
Revisions in estimated cash flows	12,397
Liability settled or disposed in current period	(540)
Accretion	2,090
Impact of fresh start accounting	0
Ending balance	106,481	$ 92,413
Less: current portion	66,154
Asset retirement obligations, net of current	40,327
Predecessor
Asset Retirement Obligation, Roll Forward Analysis
Beginning balance	$ 92,413	103,578	$ 54,402	$ 424,117
Liability incurred upon acquiring and drilling wells		505	1,662	4,968
Revisions in estimated cash flows		0	44,060	(5,848)
Liability settled or disposed in current period		(36,979)	(1,023)	(377,927)
Accretion		4,365	4,477	9,092
Impact of fresh start accounting		20,944	0	0
Ending balance		92,413	103,578	54,402
Less: current portion		65,678	8,399	0
Asset retirement obligations, net of current		26,735	$ 95,179	54,402
Predecessor | WTO Properties
Asset Retirement Obligation, Roll Forward Analysis
Liability settled or disposed in current period		$ (34,100)
Predecessor | Gulf of Mexico Properties
Asset Retirement Obligation, Roll Forward Analysis
Liability settled or disposed in current period				$ (366,000)

Commitments and Contingencies -

Commitments and Contingencies - Narrative (Details) - USD ($) $ in Thousands	Dec. 20, 2016	Jun. 16, 2016	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Predecessor
Commitments and Contingencies Disclosure [Line Items]
Employee termination benefits				$ 18,356	$ 12,451	$ 8,874
Estimated litigation claims				20,478
Predecessor | SEC
Commitments and Contingencies Disclosure [Line Items]
Amount of claims filed under bankruptcy		$ 1,200
Estimated liability				1,400
Successor
Commitments and Contingencies Disclosure [Line Items]
Employee termination benefits			$ 12,334
Successor | SEC
Commitments and Contingencies Disclosure [Line Items]
Estimated liability			100
Settlement amount	$ 1,400
Employee Severance | Predecessor
Commitments and Contingencies Disclosure [Line Items]
Employee termination benefits				$ 18,400
Employee Severance | Successor
Commitments and Contingencies Disclosure [Line Items]
Employee termination benefits			12,300
Employee termination benefits payable			$ 5,700
Gulf Properties | Employee Severance | Predecessor
Commitments and Contingencies Disclosure [Line Items]
Employee termination benefits					$ 12,500	$ 8,900

Equity - Successor Equity (Deta

Equity - Successor Equity (Details) - USD ($) $ / shares in Units, $ in Thousands	Oct. 01, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2016	Jun. 30, 2015
Successor
Class of Stock [Line Items]
Common stock, issued (in shares)	18,900,000	18,900,000		19,635,000
Common stock, par value (in dollars per share)				$ 0.001
Shares authorized (in shares)				250,000,000
Additional paid-in capital - stockholder receivable				$ 0
Successor | New Common Stock
Class of Stock [Line Items]
Common stock, issued (in shares)	18,900,000	18,900,000
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Shares reserved for future distribution	400,000	400,000
Successor | Series A Warrants
Class of Stock [Line Items]
Number of shares to be issued	4,900,000	4,900,000
Shares issued	4,500,000
Exercise price of warrants (in usd per share)	$ 41.34	$ 41.34
Successor | Series B Warrants
Class of Stock [Line Items]
Number of shares to be issued	2,100,000	2,100,000
Shares issued	1,900,000
Exercise price of warrants (in usd per share)	$ 42.03	$ 42.03
Predecessor
Class of Stock [Line Items]
Common stock, issued (in shares)			635,584,000
Common stock, par value (in dollars per share)			$ 0.001
Shares authorized (in shares)			1,800,000,000
Shares held in treasury (in shares)			2,100,000
Common stock issued for debt (in shares)		84,400,000	92,800,000
Additional paid-in capital - stockholder receivable			$ (1,250)
Predecessor | 7.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Shares converted			200,000
Predecessor | Common Stock and Preferred Stock
Class of Stock [Line Items]
Shares authorized, par value (usd per share)					$ 0.001
Predecessor | Senior Notes | Common Stock
Class of Stock [Line Items]
Common stock issued for debt (in shares)			28,000,000
Predecessor | Convertible Debt
Class of Stock [Line Items]
Debt conversion, original debt, amount		$ 232,100	$ 255,300
Predecessor | Convertible Debt | Common Stock
Class of Stock [Line Items]
Common stock issued for debt (in shares)		84,400,000	92,800,000
Predecessor | 7.5% Senior Notes Due 2021 And 8.125% Senior Notes Due 2022 | Senior Notes
Class of Stock [Line Items]
Debt conversion, original debt, amount			$ 50,000
Predecessor | Minimum | Common Stock
Class of Stock [Line Items]
Shares authorized (in shares)					800,000,000
Predecessor | Minimum | Preferred Stock
Class of Stock [Line Items]
Shares authorized (in shares)					50,000,000
Predecessor | Minimum | Common Stock and Preferred Stock
Class of Stock [Line Items]
Shares authorized (in shares)					850,000,000
Predecessor | Maximum | Common Stock
Class of Stock [Line Items]
Shares authorized (in shares)					1,800,000,000
Predecessor | Maximum | Preferred Stock
Class of Stock [Line Items]
Shares authorized (in shares)					50,000,000
Predecessor | Maximum | Common Stock and Preferred Stock
Class of Stock [Line Items]
Shares authorized (in shares)					1,850,000,000

Equity - Preferred Stock Terms

Equity - Preferred Stock Terms (Details) - $ / shares	Oct. 01, 2016	Dec. 31, 2015
8.5% Convertible perpetual preferred stock
Class of Stock [Line Items]
Preferred stock, dividend rate, percentage		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%
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
Predecessor
Class of Stock [Line Items]
Common Stock, Converted from Convertible Preferred Stock		3,000,000
Predecessor | 8.5% Convertible perpetual preferred stock
Class of Stock [Line Items]
Preferred stock, dividend rate, percentage	8.50%	8.50%
Predecessor | 7.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Preferred stock, dividend rate, percentage	7.00%	7.00%

Equity - Preferred Stock Divide

Equity - Preferred Stock Dividends (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	Oct. 01, 2016	Aug. 17, 2015	May 15, 2015	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
8.5% Convertible perpetual preferred stock
Class of Stock [Line Items]
Preferred stock, dividend rate, percentage					8.50%
7.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Preferred stock, dividend rate, percentage					7.00%
Predecessor
Class of Stock [Line Items]
Dividends satisfied in shares of common stock				$ 0	$ 16,188	$ 0
Predecessor | 8.5% Convertible perpetual preferred stock
Class of Stock [Line Items]
Preferred stock, dividend rate, percentage	8.50%				8.50%
Dividends paid in cash				0	$ 11,262	22,525
Dividends satisfied in shares of common stock				0	11,262	0
Accrued dividends at period end				0	8,447	8,447
Dividends in arrears				11,262	$ 0	0
Predecessor | 7.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Preferred stock, dividend rate, percentage	7.00%				7.00%
Dividends paid in cash				0	$ 0	21,000
Dividends satisfied in shares of common stock				0	10,500	0
Accrued dividends at period end				0	13,125	2,625
Dividends in arrears				21,000	$ 10,500	0
Predecessor | 6.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Preferred stock, dividend rate, percentage					6.00%
Dividends paid in cash				0	$ 0	12,000
Accrued dividends at period end				$ 0	$ 0	$ 0
Predecessor | Common Stock
Class of Stock [Line Items]
Convertible perpetual preferred stock dividends (in shares)					24,289
Predecessor | Common Stock | 8.5% Convertible perpetual preferred stock
Class of Stock [Line Items]
Convertible perpetual preferred stock dividends (in shares)					18,600
Multiplier used in determining price of shares issued (percentage)					95.00%
Market value of common stock issued as dividends		$ 9,500
Common shares issued, value per preferred share (usd per share)		$ 3.58
Reduction to preferred stock dividends		$ 1,800
Predecessor | Common Stock | 7.0% Convertible perpetual preferred stock
Class of Stock [Line Items]
Convertible perpetual preferred stock dividends (in shares)					5,700
Multiplier used in determining price of shares issued (percentage)					95.00%
Market value of common stock issued as dividends			$ 6,700
Common shares issued, value per preferred share (usd per share)			$ 2.23
Reduction to preferred stock dividends			$ 3,800

Equity - Treasury Stock Activit

Equity - Treasury Stock Activity (Details) - Predecessor - USD ($) shares in Thousands, $ in Thousands	9 Months Ended	12 Months Ended
	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Equity, Class of Treasury Stock [Line Items]
Value of shares withheld for taxes	$ 44	$ 2,428	$ 6,373
Value of shares retired	$ 0	$ 0	$ 0
Treasury Stock
Equity, Class of Treasury Stock [Line Items]
Number of shares withheld for taxes	1,122	1,872	1,034
Value of shares withheld for taxes	$ 44	$ 2,428	$ 6,373
Number of shares retired	1,122	1,872	1,034
Value of shares retired	$ 44	$ 2,428	$ 6,373

Share-Based Compensation - Summ

Share-Based Compensation - Summary of Unvested Restricted Stock Awards (Details) - Restricted Stock - $ / shares shares in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Number of Shares
Unvested shares/units outstanding at beginning of period	0
Granted (in shares)	1,448
Vested (in shares)	(14)
Forfeited / Canceled (in shares)	(27)
Unvested shares/units outstanding at end of period	1,407	0
Weighted- Average Grant Date Fair Value (usd per share)
Unvested restricted shares outstanding at beginning of period (in usd per share)	$ 0
Granted (in usd per share)	24.32
Vested (in usd per share)	24.32
Forfeited / Canceled (in usd per share)	24.32
Unvested restricted shares outstanding at end of period (in usd per share)	$ 24.32	$ 0
Predecessor
Number of Shares
Unvested shares/units outstanding at beginning of period	0	5,626	8,556	7,643
Granted (in shares)		0	2,928	6,367
Vested (in shares)		(3,034)	(5,186)	(3,432)
Forfeited / Canceled (in shares)		(2,592)	(672)	(2,022)
Unvested shares/units outstanding at end of period		0	5,626	8,556
Weighted- Average Grant Date Fair Value (usd per share)
Unvested restricted shares outstanding at beginning of period (in usd per share)	$ 0	$ 4.85	$ 6.39	$ 6.92
Granted (in usd per share)		0	0.88	6.17
Vested (in usd per share)		5.34	4.95	7.04
Forfeited / Canceled (in usd per share)		4.31	6.38	6.60
Unvested restricted shares outstanding at end of period (in usd per share)		$ 0	$ 4.85	$ 6.39

Share-Based Compensation - Narr

Share-Based Compensation - Narrative (Details) - USD ($) shares in Thousands, $ in Millions	1 Months Ended	3 Months Ended	9 Months Ended	12 Months Ended
	Oct. 31, 2016	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted		1,448
Share-based compensation expense		$ 6.6
Share-based compensation, capitalized		0.3
Severance, compensation cost of accelerated shares		$ 4.3
Severance, number of accelerated shares		200
Unrecognized compensation cost related to unvested awards		$ 27.1
Period of recognition for unrecognized costs		2 years 9 months 18 days
Successor | 2016 Omnibus Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares authorized for issuance			4,600
Successor | 2016 Omnibus Incentive Plan | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted	1,400
Vesting period (in years)	3 years
Predecessor
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense			$ 11.2	$ 21.7	$ 22.6
Share-based compensation, capitalized			$ 1.7	$ 5.9	$ 6
Predecessor | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted			0	2,928	6,367
Vesting period (in years)			4 years
Severance, compensation cost of accelerated shares			$ 5.4
Severance, number of accelerated shares			1,300
Unrecognized compensation cost related to unvested awards			$ 5.9

Incentive and Deferred Compen91

Incentive and Deferred Compensation Plans (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Jun. 30, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014	Jan. 31, 2016
Predecessor | Deferred Compensation Plans
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Retirement plan, employer matching contribution, percent of match			100.00%	100.00%	100.00%
Retirement plan, employer matching contribution, vesting period			4 years	4 years	4 years
Retirement plan, employer matching contribution, percent of employees' gross pay (up to)			10.00%	10.00%	10.00%
Retirement plan, cost recognized			$ 4.9	$ 7.9	$ 8.7
Percent of employee contributions vesting immediately			100.00%	100.00%	100.00%
Predecessor | Annual Incentive Plan
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Accrued bonuses				$ 21.6
Predecessor | 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%
Predecessor | 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%
Predecessor | Performance Incentive Plan
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Payments to employees		$ 17.8
Predecessor | Performance Incentive Plan | Minimum
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Incentive plans, payout percentages of target values						0.00%
Predecessor | Performance Incentive Plan | Maximum
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Incentive plans, payout percentages of target values						200.00%
Successor
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Deferred compensation plan assets to be distributed to participants	$ 7.5
Successor | Deferred Compensation Plans
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Retirement plan, employer matching contribution, percent of match	100.00%
Retirement plan, employer matching contribution, vesting period	4 years
Retirement plan, employer matching contribution, percent of employees' gross pay (up to)	10.00%
Retirement plan, cost recognized	$ 0.9
Percent of employee contributions vesting immediately	100.00%
Successor | Performance Incentive Plan
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Payments to employees	$ 7.1
Accrued bonuses	$ 15.8

Income Taxes - (Benefit) Provis

Income Taxes - (Benefit) Provision for Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Current
Federal	$ 0
State	9
Current, total	9
Deferred
Federal	0
State	0
Deferred, total	0
Total provision (benefit)	9
Successor | Noncontrolling Interest
Deferred
Total provision (benefit)	0
Successor | Parent
Deferred
Total provision (benefit)	$ 9
Predecessor
Current
Federal		$ 0	$ 0	$ (1,160)
State		11	123	(1,133)
Current, total		11	123	(2,293)
Deferred
Federal		0	0	0
State		0	0	0
Deferred, total		0	0	0
Total provision (benefit)		11	123	(2,293)
Predecessor | Noncontrolling Interest
Deferred
Total provision (benefit)		0	90	283
Predecessor | Parent
Deferred
Total provision (benefit)		$ 11	$ 33	$ (2,576)

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	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Reconciliation Of Provision Of Income Taxes [Line Items]
Total provision (benefit)	$ 9
Successor | Parent
Reconciliation Of Provision Of Income Taxes [Line Items]
Computed at federal statutory rate	(116,891)
State taxes, net of federal benefit	(3,696)
Non-deductible expenses	144
Non-deductible debt costs	0
Stock-based compensation	306
Net effects of consolidating the non-controlling interests’ tax provisions	0
Discharge of debt and other reorganization related items	0
Change in valuation allowance	120,144
Other	2
Total provision (benefit)	$ 9
Predecessor
Reconciliation Of Provision Of Income Taxes [Line Items]
Total provision (benefit)		$ 11	$ 123	$ (2,293)
Predecessor | Parent
Reconciliation Of Provision Of Income Taxes [Line Items]
Computed at federal statutory rate		504,283	(1,512,325)	122,362
State taxes, net of federal benefit		10,512	(19,988)	4,145
Non-deductible expenses		462	816	1,895
Non-deductible debt costs		22,694	10,228	0
Stock-based compensation		5,884	6,700	1,467
Net effects of consolidating the non-controlling interests’ tax provisions		0	218,196	(34,614)
Discharge of debt and other reorganization related items		359,278	0	0
Change in valuation allowance		(903,102)	1,296,405	(96,769)
Other		0	1	(1,062)
Total provision (benefit)		$ 11	$ 33	$ (2,576)

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Deferred tax liabilities
Investments	$ 275,128
Derivative contracts	0
Long-term debt	0
Total deferred tax liabilities	275,128
Deferred tax assets
Property, plant and equipment	751,683
Derivative contracts	11,274
Allowance for doubtful accounts	1,487
Net operating loss carryforwards	527,079
Compensation and benefits	14,494
Alternative minimum tax credits and other carryforwards	43,770
Asset retirement obligations	40,399
CO2 under-delivery shortfall penalty	0
Other	4,663
Total deferred tax assets	1,394,849
Valuation allowance	(1,119,721)
Net deferred tax liability	$ 0
Predecessor
Deferred tax liabilities
Investments		$ 138,310
Derivative contracts		30,989
Long-term debt		10,017
Total deferred tax liabilities		179,316
Deferred tax assets
Property, plant and equipment		807,275
Derivative contracts		0
Allowance for doubtful accounts		18,702
Net operating loss carryforwards		1,190,799
Compensation and benefits		18,607
Alternative minimum tax credits and other carryforwards		44,302
Asset retirement obligations		38,314
CO2 under-delivery shortfall penalty		40,654
Other		4,305
Total deferred tax assets		2,162,958
Valuation allowance		(1,983,642)	$ (649,600)
Net deferred tax liability		$ 0

Income Taxes - Unrecognized Tax

Income Taxes - Unrecognized Tax Benefits (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015
Successor
Reconciliation of Unrecognized Tax Benefits
Unrecognized tax benefit at January 1	$ 81
Changes to unrecognized tax benefits related to a prior year	3
Unrecognized tax benefit at December 31	84	$ 81
Predecessor
Reconciliation of Unrecognized Tax Benefits
Unrecognized tax benefit at January 1	$ 81	81	$ 77
Changes to unrecognized tax benefits related to a prior year		0	4
Unrecognized tax benefit at December 31		$ 81	$ 81

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Operating Loss Carryforwards [Line Items]
Valuation allowance	$ 1,119,721
Unrecognized tax benefits	84	$ 81
Successor | Alternative Minimum Tax Credit Carryforward
Operating Loss Carryforwards [Line Items]
Alternative minimum tax credits, not subject to expiration	$ 9,300
Successor | Earliest Tax Year
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards expiration year	2,028
Successor | Latest Tax Year
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards expiration year	2,036
Successor | Domestic Tax Authority
Operating Loss Carryforwards [Line Items]
Federal net operating loss carryovers	$ 1,300,000
Predecessor
Operating Loss Carryforwards [Line Items]
Valuation allowance			$ 1,983,642	$ 649,600
Unrecognized tax benefits		81	$ 81	$ 77
Reorganization Adjustments | Domestic Tax Authority
Operating Loss Carryforwards [Line Items]
Federal net operating loss carryovers		$ 3,700,000

Income Taxes - Periods Open to

Income Taxes - Periods Open to Tax Examination (Details) - Successor	3 Months Ended
	Dec. 31, 2016
Domestic Tax Authority | Earliest Tax Year
Income Tax Contingency [Line Items]
Open tax year	2,013
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	2,012
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	Oct. 01, 2016	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Oct. 01, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Effect of dilutive securities
net (Loss) Income, Warrants											$ 0
Successor
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net (Loss) Income, Basic		$ (333,982)
Weighted Average Shares, basic		18,967
(Loss) Earnings Per Share, Basic (in dollars per share)		$ (17.61)
Effect of dilutive securities
Net (Loss) Income, Restricted stock		$ 0
Weighted Average Shares, Restricted stock		0
Weighted Average Shares, Warrants		0
Weighted Average Shares, Convertible notes (in shares)		0
Net (Loss) Income, Diluted		$ (333,982)
Weighted Average Shares, Diluted (in shares)		18,967
(Loss) Earnings Per Share, Diluted (in dollars per share)		$ (17.61)
Predecessor
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net (Loss) Income, Basic	$ 2,674,271		$ (404,337)	$ (521,351)	$ (324,107)	$ (664,579)	$ (649,526)	$ (1,375,556)	$ (1,045,834)	$ 1,424,476		$ (3,735,495)	$ 203,260
Weighted Average Shares, basic										708,928		521,936	479,644
(Loss) Earnings Per Share, Basic (in dollars per share)	$ 3.72		$ (0.56)	$ (0.73)	$ (0.47)	$ (1.13)	$ (1.23)	$ (2.78)	$ (2.19)	$ 2.01		$ (7.16)	$ 0.42
Effect of dilutive securities
Net (Loss) Income, Restricted stock										$ 0		$ 0	$ 0
Weighted Average Shares, Restricted stock										0		0	2,181
Net (Loss) Income, Convertible notes											$ 0	$ 0
Weighted Average Shares, Convertible notes (in shares)												0
Net (Loss) Income, Convertible preferred stock												$ 0	$ 6,500
Weighted Average Shares, Convertible preferred stock												0	17,918
Net (Loss) Income, Diluted										$ 1,424,476		$ (3,735,495)	$ 209,760
Weighted Average Shares, Diluted (in shares)										708,928		521,936	499,743
(Loss) Earnings Per Share, Diluted (in dollars per share)	$ 3.72		$ (0.56)	$ (0.73)	$ (0.47)	$ (1.13)	$ (1.23)	$ (2.78)	$ (2.19)	$ 2.01		$ (7.16)	$ 0.42

(Loss) Earnings per Share - C99

(Loss) Earnings per Share - Calculation of Weighted Average Common Shares Outstanding used in Computation of Diluted Earnings Per Share (Additional Information) (Details) - shares	Oct. 01, 2016	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
8.5% Convertible perpetual preferred stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Preferred stock, dividend rate, percentage					8.50%
7.0% Convertible perpetual preferred stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Preferred stock, dividend rate, percentage					7.00%
Successor | Restricted Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share		0	0
Successor | New Convertible Notes
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share		14,600,000
Successor | 8.5% Convertible perpetual preferred stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Preferred stock, dividend rate, percentage				0.00%
Successor | 7.0% Convertible perpetual preferred stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Preferred stock, dividend rate, percentage				0.00%
Predecessor | Restricted Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share					0
Predecessor | Convertible Preferred Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share					71,200,000	71,700,000
Predecessor | Convertible Debt Securities
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share					48,500,000
Predecessor | Warrants
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share				0
Predecessor | 8.125% Convertible Senior Notes due 2022
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Long-term debt, fixed interest rate					8.125%
Predecessor | 7.5% Convertible Senior Notes due 2023
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Long-term debt, fixed interest rate					7.50%
Predecessor | 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%
Predecessor | 6.0% Convertible perpetual preferred stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Preferred stock, dividend rate, percentage					6.00%
Predecessor | 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%

Subsequent Events - Narrative (

Subsequent Events - Narrative (Details) shares in Millions	Feb. 10, 2017USD ($)awellshares	Oct. 01, 2016USD ($)	Feb. 09, 2017USD ($)shares
New First Lien Exit Facility | Revolving Credit Facility
Subsequent Event [Line Items]
Principal amount of commitments		$ 425,000,000
Cash collateral account		50,000,000
Liquidity requirement		$ 20,000,000
LIBOR | New First Lien Exit Facility | Revolving Credit Facility
Subsequent Event [Line Items]
Basis spread on variable rate		4.75%
Variable rate floor		1.00%
Subsequent Event
Subsequent Event [Line Items]
Number of acres acquired | a	13,000
Cash paid for acres	$ 47,800,000
Number of wells acquired | well	4
Subsequent Event | Amended New Credit Facility | Revolving Credit Facility
Subsequent Event [Line Items]
Principal amount of commitments	$ 600,000,000
Borrowing base	425,000,000
Subsequent Event | New Convertible Notes | Convertible Debt
Subsequent Event [Line Items]
Debt conversion, original debt, amount	$ 263,700,000		$ 5,100,000
Common stock issued for debt (in shares) | shares	14.1		0.3
Subsequent Event | LIBOR | Amended New Credit Facility | Revolving Credit Facility
Subsequent Event [Line Items]
Variable rate floor	0.00%
Subsequent Event | Minimum | LIBOR | Amended New Credit Facility | Revolving Credit Facility
Subsequent Event [Line Items]
Basis spread on variable rate	3.00%
Subsequent Event | Minimum | Base Rate | Amended New Credit Facility | Revolving Credit Facility
Subsequent Event [Line Items]
Basis spread on variable rate	2.00%
Subsequent Event | Maximum | LIBOR | Amended New Credit Facility | Revolving Credit Facility
Subsequent Event [Line Items]
Basis spread on variable rate	4.00%
Subsequent Event | Maximum | Base Rate | Amended New Credit Facility | Revolving Credit Facility
Subsequent Event [Line Items]
Basis spread on variable rate	3.00%

Supplemental Information on 101

Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited) - Capitalized Costs Related to Oil and Natural Gas Producing Activities (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Oil and natural gas properties
Proved	$ 840,201
Unproved	74,937
Total oil and natural gas properties	915,138
Less: accumulated depreciation, depletion and impairment	(353,030)
Net oil and natural gas properties capitalized costs	$ 562,108
Predecessor
Oil and natural gas properties
Proved		$ 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

Supplemental Information on 102

Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited) - Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Acquisitions of properties
Proved	$ 5,142
Unproved	5,491
Exploration	0
Development	27,429
Total cost incurred	$ 38,062
Predecessor
Acquisitions of properties
Proved		$ 3,897	$ 35,376	$ 73,370
Unproved		1,899	210,065	123,649
Exploration		1,234	29,297	41,070
Development		149,924	571,562	1,288,395
Total cost incurred		$ 156,954	846,300	1,526,484
Predecessor | Seismic Costs
Acquisitions of properties
Exploration			$ 7,100	$ 10,800

Supplemental Information on 103

Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited) - Results of Operations from Oil and Natural Gas Producing Activities (Unaudited) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Revenues	$ 98,307
Expenses
Production costs	27,640
Depreciation and depletion	33,971
Accretion of asset retirement obligations	2,090
Impairment	319,087
Total expenses	382,788
(Loss) income before income taxes	(284,481)
Income tax expense (benefit)	8
Results of operations for oil and natural gas producing activities (excluding corporate overhead and interest costs)	$ (284,489)
Predecessor
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Revenues		$ 279,971	$ 707,434	$ 1,420,879
Expenses
Production costs		135,715	324,141	377,819
Depreciation and depletion		86,613	319,913	434,295
Accretion of asset retirement obligations		4,365	4,477	9,092
Impairment		657,392	4,473,787	164,779
Total expenses		884,085	5,122,318	985,985
(Loss) income before income taxes		(604,114)	(4,414,884)	434,894
Income tax expense (benefit)		(5)	126	(2,852)
Results of operations for oil and natural gas producing activities (excluding corporate overhead and interest costs)		$ (604,109)	$ (4,415,010)	$ 437,746

Supplemental Information on 104

Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited) - Summary of Changes in Estimated Oil and Natural Gas Reserves (Unaudited) (Details) Mcf in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016MBblsMcf	Oct. 01, 2016MBblsMcf	Dec. 31, 2015MBblsMcf	Dec. 31, 2014MBblsMcf	Dec. 31, 2013MBblsMcf
Oil | Non-controlling Interest
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Proved developed and undeveloped reserves, beginning balance		7,004	11,027
Proved developed and undeveloped reserves, ending balance			7,004	11,027
NGL | Non-controlling Interest
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Proved developed and undeveloped reserves, beginning balance		3,694	4,761
Proved developed and undeveloped reserves, ending balance			3,694	4,761
Natural Gas | Non-controlling Interest
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Proved developed and undeveloped reserves, beginning balance | Mcf		50,508	70,833
Proved developed and undeveloped reserves, ending balance | Mcf			50,508	70,833
Predecessor | Oil
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Proved developed and undeveloped reserves, beginning balance	27,252	77,911	126,031	142,641
Adoption of ASU 2015-02		(6,971)
Revisions of previous estimates		(39,973)	(70,708)	(18,687)
Acquisitions of new reserves			22,447	1,009
Extensions and discoveries		987	9,741	37,603
Sales of reserves in place		(387)		(25,659)
Production		(4,315)	(9,600)	(10,876)
Proved developed and undeveloped reserves, ending balance		27,252	77,911	126,031
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)		24,541	48,639	79,022	83,893
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)		2,711	29,272	47,009	58,748
Predecessor | NGL
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Proved developed and undeveloped reserves, beginning balance	33,019	61,075	91,786	59,052
Adoption of ASU 2015-02		(3,695)
Revisions of previous estimates		(21,475)	(37,384)	11,103
Acquisitions of new reserves			2,460	441
Extensions and discoveries		472	9,257	27,500
Sales of reserves in place		0		(2,516)
Production		(3,358)	(5,044)	(3,794)
Proved developed and undeveloped reserves, ending balance		33,019	61,075	91,786
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)		30,238	51,089	56,823	35,807
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)		2,781	9,986	34,963	23,245
Predecessor | 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	466,328	1,113,840	1,788,233	1,390,429
Adoption of ASU 2015-02 | Mcf		(50,508)
Revisions of previous estimates | Mcf		(415,568)	(759,106)	167,589
Acquisitions of new reserves | Mcf			15,952	12,527
Extensions and discoveries | Mcf		7,955	160,865	467,185
Sales of reserves in place | Mcf		(145,267)		(163,800)
Production | Mcf		(44,124)	(92,104)	(85,697)
Proved developed and undeveloped reserves, ending balance | Mcf		466,328	1,113,840	1,788,233
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas) | Mcf		428,050	964,617	1,203,447	951,609
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas) | Mcf		38,278	149,223	584,786	438,820
Successor | Oil
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Revisions of previous estimates	23,978
Extensions and discoveries	2,868
Production	(1,214)
Proved developed and undeveloped reserves, ending balance	52,884
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	25,911
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	26,973
Successor | NGL
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Revisions of previous estimates	1,139
Extensions and discoveries	448
Production	(999)
Proved developed and undeveloped reserves, ending balance	33,607
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	29,290
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	4,317
Successor | Natural Gas
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Revisions of previous estimates | Mcf	915
Extensions and discoveries | Mcf	10,309
Production | Mcf	(12,770)
Proved developed and undeveloped reserves, ending balance | Mcf	464,782
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas) | Mcf	393,028
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas) | Mcf	71,754

Supplemental Information on 105

Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited) - Calculation of Weighted Average Per Unit Prices (Unaudited) (Details)	3 Months Ended	12 Months Ended
	Dec. 31, 2016$ / Mcf$ / bbl	Dec. 31, 2015$ / Mcf$ / bbl	Dec. 31, 2014$ / Mcf$ / bbl
Successor | Oil
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)	38.59
Successor | NGL
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)	10.99
Successor | 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	1.56
Predecessor | Oil
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
Predecessor | NGL
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
Predecessor | 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

Supplemental Information on 106

Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited) - Standardized Measure of Discounted Future Cash Flows (Unaudited) (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Successor
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future cash inflows from production	$ 3,136,762
Future production costs	(1,454,798)
Future development costs	(665,516)
Future income tax expenses	(142)
Undiscounted future net cash flows	1,016,306
10% annual discount	(577,942)
Standardized measure of discounted future net cash flows	$ 438,364	$ 392,604
Predecessor
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future cash inflows from production			$ 6,387,944	$ 21,022,320
Future production costs			(2,731,542)	(6,499,366)
Future development costs			(838,945)	(1,810,201)
Future income tax expenses			(901)	(3,223,740)
Undiscounted future net cash flows			2,816,556	9,489,013
10% annual discount			(1,501,994)	(5,401,261)
Standardized measure of discounted future net cash flows		$ 392,604	1,314,562	4,087,752	$ 4,017,611
Predecessor | 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

Supplemental Information on 107

Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited) - Estimate of Changes in Standardized Measure of Discounted Future Net Cash Flows from Proved Reserves (Unaudited) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Present value, beginning balance	$ 392,604
Changes during the year
Adoption of ASU 2015-02	0
Revenues less production and other costs	(70,668)
Net changes in prices, production and other costs	35,684
Development costs incurred	7,941
Net changes in future development costs	(291,232)
Extensions and discoveries	14,986
Revisions of previous quantity estimates	308,374
Accretion of discount	9,375
Net change in income taxes	0
Purchases of reserves in-place	0
Sales of reserves in-place	0
Timing differences and other	31,300
Net change for the year	45,760
Present value, ending balance	438,364	$ 392,604
Predecessor
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Present value, beginning balance	$ 392,604	1,314,562	$ 4,087,752	$ 4,017,611
Changes during the year
Adoption of ASU 2015-02		(224,965)	0	0
Revenues less production and other costs		(144,256)	(383,293)	(1,043,060)
Net changes in prices, production and other costs		(394,173)	(3,813,465)	331,694
Development costs incurred		69,080	217,596	364,262
Net changes in future development costs		436,041	273,437	(341,183)
Extensions and discoveries		12,449	230,055	1,785,963
Revisions of previous quantity estimates		(728,254)	(1,354,778)	(77,688)
Accretion of discount		91,337	512,483	477,458
Net change in income taxes		402	1,426,333	(256,371)
Purchases of reserves in-place		0	18,429	50,958
Sales of reserves in-place		(13,314)	0	(1,058,330)
Timing differences and other		(26,305)	100,013	(163,562)
Net change for the year		(921,958)	(2,773,190)	70,141
Present value, ending balance		392,604	1,314,562	4,087,752
Noncontrolling Interest | Predecessor
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Present value, beginning balance		$ 224,600	643,300
Changes during the year
Present value, ending balance			$ 224,600	$ 643,300

Supplemental Information on 108

Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited) - Narrative (Details) Mcf in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016MBblsMcf	Oct. 01, 2016MBblsMcf	Dec. 31, 2016MMBoe	Dec. 31, 2015MMBoeMBblsMcf	Dec. 31, 2014MMBoeMBblsMcf
Reserve Quantities [Line Items]
Percentage of proved reserves estimated by the Company	6.00%		6.00%
Total downward revision | MMBoe			(105,400)
Downward revision due to change in estimates | MMBoe			94,700
Downward revision due to change in previous estimates due to pricing | MMBoe			12,100
Decrease in reserves due to sale (MMBoe) | MMBoe			24,600
Decrease in reserves due to changes in accounting | MMBoe			19,100
Upward revision of estimates due to extensions | MMBoe			7,800
Natural Gas and LNG
Reserve Quantities [Line Items]
Percent share of downward revision			85.00%
Oil
Reserve Quantities [Line Items]
Percent share of downward revision			15.00%
Successor | Oil
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas)	2,868
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)	23,978
Successor | Natural Gas
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf	10,309
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf	915
Successor | NGL
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas)	448
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)	1,139
Predecessor
Reserve Quantities [Line Items]
Expected period without drilling activity					5 years
Acquisitions of new reserves (MMBoe) | MMBoe					3.5
Predecessor | Oil
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas)		987		9,741	37,603
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)		(39,973)		(70,708)	(18,687)
Predecessor | Natural Gas
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf		7,955		160,865	467,185
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf		(415,568)		(759,106)	167,589
Predecessor | NGL
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas)		472		9,257	27,500
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)		(21,475)		(37,384)	11,103
Predecessor | Gulf Properties
Reserve Quantities [Line Items]
Decrease in reserves due to sale (MMBoe) | MMBoe					55.5
Predecessor | Lower Commodity Price | Oil
Reserve Quantities [Line Items]
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)				(54,000)
Predecessor | Lower Commodity Price | Natural Gas
Reserve Quantities [Line Items]
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf				(687,000)
Predecessor | Lower Commodity Price | NGL
Reserve Quantities [Line Items]
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)				(36,000)
Predecessor | North Park Basin, Jackson County, Colorado [Member]
Reserve Quantities [Line Items]
Acquisitions of new reserves (MMBoe) | MMBoe				27.6
Predecessor | Mid-Continent and Permian Basin | Oil
Reserve Quantities [Line Items]
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)					(2,000)
Predecessor | Mid-Continent | Oil
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas)				9,700
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)				(16,000)	(8,000)
Predecessor | Mid-Continent | Natural Gas
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf				160,900
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf				(74,000)
Predecessor | Mid-Continent | NGL
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas)				9,300
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)				(1,000)
Predecessor | Permian Properties | Oil
Reserve Quantities [Line Items]
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas)					(9,000)

Quarterly Financial Results 109

Quarterly Financial Results (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Thousands	Oct. 01, 2016	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Predecessor
Quarterly Financial Information [Line Items]
Total revenues	$ 0		$ 104,056	$ 99,421	$ 90,332	$ 143,642	$ 180,152	$ 229,607	$ 215,308	$ 293,809	$ 768,709	$ 1,558,758
Loss from operations	0		(357,338)	(275,310)	(273,555)	(959,406)	(1,059,733)	(1,535,083)	(1,088,456)	(906,203)	(4,642,678)	590,224
Net (loss) income	2,674,271		(404,337)	(515,911)	(313,226)	(783,961)	(796,485)	(1,588,731)	(1,151,874)	1,440,797	(4,321,051)	351,898
(Loss applicable) income available to SandRidge Energy, Inc. common stockholders	$ 2,674,271		$ (404,337)	$ (521,351)	$ (324,107)	$ (664,579)	$ (649,526)	$ (1,375,556)	$ (1,045,834)	$ 1,424,476	$ (3,735,495)	$ 203,260
(Loss applicable) income available per share to SandRidge Energy, Inc. common stockholders
Basic (in dollars per share)	$ 3.72		$ (0.56)	$ (0.73)	$ (0.47)	$ (1.13)	$ (1.23)	$ (2.78)	$ (2.19)	$ 2.01	$ (7.16)	$ 0.42
Diluted (in dollars per share)	$ 3.72		$ (0.56)	$ (0.73)	$ (0.47)	$ (1.13)	$ (1.23)	$ (2.78)	$ (2.19)	$ 2.01	$ (7.16)	$ 0.42
Impairment			$ 354,500	$ 253,600	$ 110,100	$ 886,800	$ 1,100,000	$ 1,500,000	$ 1,100,000	$ 718,194	$ 4,534,689	$ 192,768
Loss on settlement of contract					89,100					90,184	50,976	0
Loss (gain) on derivative contracts						$ (14,000)	$ (42,200)	$ 33,000	$ (49,800)	4,823	(73,061)	(334,011)
Gain on extinguishment of debt					$ 41,300					$ 41,179	$ 641,131	$ 0
Gain (loss) on reorganization items	$ 2,700,000		$ (42,800)	$ (200,900)
Successor
Quarterly Financial Information [Line Items]
Total revenues		$ 98,456
Loss from operations		(336,345)
Net (loss) income		(333,982)
(Loss applicable) income available to SandRidge Energy, Inc. common stockholders		$ (333,982)
(Loss applicable) income available per share to SandRidge Energy, Inc. common stockholders
Basic (in dollars per share)		$ (17.61)
Diluted (in dollars per share)		$ (17.61)
Impairment		$ 319,087
Loss on settlement of contract		0
Loss (gain) on derivative contracts		25,652
Gain on extinguishment of debt		$ 0

Uncategorized Items - sd-201612

Label	Element	Value
Predecessor [Member]
Additional Paid in Capital Substantial Premium Component of Convertible Debt	sd_AdditionalPaidinCapitalSubstantialPremiumComponentofConvertibleDebt	$ 163,879,000
Stock Issued During Period, Value, Warrants	sd_StockIssuedDuringPeriodValueWarrants	88,382,000
Stock Issued During Period, Value, New Issues	us-gaap_StockIssuedDuringPeriodValueNewIssues	575,163,000
Retained Earnings [Member] | Predecessor [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(5,311,140,000)
Treasury Stock [Member] | Predecessor [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(5,218,000)
Additional Paid-in Capital [Member] | Predecessor [Member]
Additional Paid in Capital Substantial Premium Component of Convertible Debt	sd_AdditionalPaidinCapitalSubstantialPremiumComponentofConvertibleDebt	163,879,000
Stock Issued During Period, Value, New Issues	us-gaap_StockIssuedDuringPeriodValueNewIssues	575,144,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ 5,314,405,000
Warrant [Member] | Predecessor [Member]
Stock Issued During Period, Shares, Warrants	sd_StockIssuedDuringPeriodSharesWarrants	6,442,000
Stock Issued During Period, Value, Warrants	sd_StockIssuedDuringPeriodValueWarrants	$ 88,382,000
Preferred Stock [Member] | Predecessor [Member]
Preferred Stock, Shares Outstanding	us-gaap_PreferredStockSharesOutstanding	5,247,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ 6,000
Noncontrolling Interest [Member] | Predecessor [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ (21,000)
Common Stock [Member] | Predecessor [Member]
Common Stock, Shares, Outstanding	us-gaap_CommonStockSharesOutstanding	718,500,000
Stock Issued During Period, Value, New Issues	us-gaap_StockIssuedDuringPeriodValueNewIssues	$ 19,000
Stock Issued During Period, Shares, New Issues	us-gaap_StockIssuedDuringPeriodSharesNewIssues	18,932,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ 718,000