SandRidge Energy (SD) 10-K 22 Feb 18 2017 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Feb. 15, 2018	Jun. 30, 2017
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, 2017
Document Fiscal Year Focus	2,017
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			$ 586.9
Entity Common Stock, Shares Outstanding		35,641,907

Consolidated Balance Sheets

Consolidated Balance Sheets - Successor - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Current assets
Cash and cash equivalents	$ 99,143	$ 121,231
Restricted cash - collateral	0	50,000
Restricted cash - other	2,165	2,840
Accounts receivable, net	71,277	74,097
Derivative contracts	1,310	0
Prepaid expenses	5,248	5,375
Other current assets	15,954	3,633
Total current assets	195,097	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 at December 31, 2016)	1,056,806	840,201
Unproved	100,884	74,937
Less: accumulated depreciation, depletion and impairment	(460,431)	(353,030)
Net oil and natural gas properties capitalized costs	697,259	562,108
Other property, plant and equipment, net	225,981	255,824
Other assets	1,290	6,284
Total assets	1,119,627	1,081,392
Current liabilities
Accounts payable and accrued expenses	139,155	116,517
Derivative contracts	10,627	27,538
Asset retirement obligations	41,017	66,154
Other current liabilities	8,115	3,497
Total current liabilities	198,914	213,706
Long-term debt	37,502	305,308
Derivative contracts	3,568	2,176
Asset retirement obligations	36,527	40,327
Other long-term obligations	3,176	6,958
Total liabilities	279,687	568,475
Commitments and contingencies (Note 15)
Stockholders’ Equity
Common stock	36	20
Warrants	88,500	88,381
Additional paid-in capital	1,038,324	758,498
Accumulated deficit	(286,920)	(333,982)
Total stockholders’ equity	839,940	512,917
Total liabilities and stockholders’ equity	$ 1,119,627	$ 1,081,392

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - Successor - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Development and project costs excluded from amortization	$ 0	$ 16.7
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares authorized (in shares)	250,000,000	250,000,000
Common stock, issued (in shares)	35,650,000	21,042,000
Common stock, outstanding (in shares)	35,650,000	19,635,000

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, 2017	Dec. 31, 2015
Successor
Revenues
Oil, natural gas and NGL	$ 98,307		$ 356,210
Other	149		1,089
Total revenues	98,456		357,299
Expenses
Production	24,997		102,728
Production taxes	2,643		13,644
Depreciation and depletion—oil and natural gas	36,061		118,035
Depreciation and amortization—other	3,922		13,852
Impairment	319,087		4,019
General and administrative	9,837		76,024
Terminated merger costs	0		8,162
Employee termination benefits	12,334		4,815
(Gain) loss on derivative contracts	25,652		(24,090)
Loss on settlement of contract	0		0
Other operating expenses	268		479
Total expenses	434,801		317,668
Income (loss) from operations	(336,345)		39,631
Other (expense) income
Interest expense	(372)		(3,868)
Gain on extinguishment of debt	0		0
Gain on reorganization items, net	0		0
Other income, net	2,744		2,550
Total other (expense) income	2,372		(1,318)
Income (loss) before income taxes	(333,973)		38,313
Income tax (benefit) expense	9		(8,749)
Net income (loss)	(333,982)		47,062
Less: net loss attributable to noncontrolling interest	0		0
Net income (loss) attributable to SandRidge Energy, Inc.	(333,982)		47,062
Preferred stock dividends	0		0
Income available (loss applicable) to SandRidge Energy, Inc. common stockholders	$ (333,982)		$ 47,062
Earnings (loss) per share
Basic (in dollars per share)	$ (17.61)		$ 1.45
Diluted (in dollars per share)	$ (17.61)		$ 1.44
Weighted average number of common shares outstanding
Basic (in shares)	18,967		32,442
Diluted (in shares)	18,967		32,663
Predecessor
Revenues
Oil, natural gas and NGL		$ 279,971		$ 707,434
Other		13,838		61,275
Total revenues		293,809		768,709
Expenses
Production		129,608		308,701
Production taxes		6,107		15,440
Depreciation and depletion—oil and natural gas		90,978		324,390
Depreciation and amortization—other		21,323		47,382
Impairment		718,194		4,534,689
General and administrative		116,091		137,715
Terminated merger costs		0		0
Employee termination benefits		18,356		12,451
(Gain) loss on derivative contracts		4,823		(73,061)
Loss on settlement of contract		90,184		50,976
Other operating expenses		4,348		52,704
Total expenses		1,200,012		5,411,387
Income (loss) from operations		(906,203)		(4,642,678)
Other (expense) income
Interest expense		(126,099)		(321,421)
Gain on extinguishment of debt		41,179		641,131
Gain on reorganization items, net		2,430,599		0
Other income, net		1,332		2,040
Total other (expense) income		2,347,011		321,750
Income (loss) before income taxes		1,440,808		(4,320,928)
Income tax (benefit) expense		11		123
Net income (loss)		1,440,797		(4,321,051)
Less: net loss attributable to noncontrolling interest		0		(623,506)
Net income (loss) attributable to SandRidge Energy, Inc.		1,440,797		(3,697,545)
Preferred stock dividends		16,321		37,950
Income available (loss applicable) to SandRidge Energy, Inc. common stockholders		$ 1,424,476		$ (3,735,495)
Earnings (loss) per share
Basic (in dollars per share)		$ 2.01		$ (7.16)
Diluted (in dollars per share)		$ 2.01		$ (7.16)
Weighted average number of common shares outstanding
Basic (in shares)		708,928		521,936
Diluted (in shares)		708,928		521,936

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, 2014		5,650
Beginning Balance (in shares) (Predecessor) at Dec. 31, 2014			484,819
Beginning 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)
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
Cash paid for tax withholdings on vested stock awards | Predecessor	(2,428)				(2,428)
Common stock issued for debt | Predecessor	1,250				1,250
Issuance (cancellation) of restricted stock awards, net (in shares) | Predecessor			1,514
Issuance (cancellations) of restricted stock awards, net | Predecessor	0		$ 5		(5)
Common stock issued for debt (in shares) | Predecessor			120,881
Common stock issued for debt | Predecessor	63,299		$ 121		63,178
Common stock issued for preferred stock (in shares) | Predecessor		(230)	2,968
Common stock issued for preferred stock or warrants | Predecessor	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
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)
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
Cash paid for tax withholdings on vested stock awards | Predecessor	(44)				(44)
Issuance (cancellation) of restricted stock awards, net (in shares) | Predecessor			(2,184)
Issuance (cancellations) of restricted stock awards, net | Predecessor	0		$ 2		(2)
Common stock issued for debt (in shares) | Predecessor			84,390
Common stock issued for debt | Predecessor	4,409		$ 84		4,325
Common stock issued for preferred stock (in shares) | Predecessor		(173)	2,220
Common stock issued for preferred stock or warrants | 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 (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
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
Stock-based compensation | Successor	6,581				6,581
Cash paid for tax withholdings on vested stock awards | Successor	(110)				(110)
Issuance of stock awards, net of cancellations (in shares) | Successor			10
Issuance of stock awards, net of cancellations | Successor	0		$ 0		0
Common stock issued for debt (in shares) | Successor			693
Common stock issued for debt | Successor	13,001		$ 1		13,000
Common stock issued for preferred stock or warrants | 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		(333,982)
Increase (Decrease) in Stockholders' Equity
Stock-based compensation | Successor	17,912				17,912
Cash paid for tax withholdings on vested stock awards | Successor	(6,730)				(6,730)
Issuance of stock awards, net of cancellations (in shares) | Successor			1,583
Issuance of stock awards, net of cancellations | Successor	0		$ 2		(2)
Common stock issued for debt (in shares) | Successor			14,328
Common stock issued for debt | Successor	268,779		$ 14		268,765
Net (loss) income | Successor	47,062						47,062
Issuance of common stock (in shares) | Successor			104
Issuance of common stock | Successor	0
Issuance of Successor warrants (in shares) | Predecessor				128
Issuance of Successor warrants | Predecessor				$ 119
Issuance of Successor warrants | Successor	$ 0				(119)
Ending Balance (in shares) (Successor) at Dec. 31, 2017	35,650		35,650	6,570
Ending Balance (Successor) at Dec. 31, 2017	$ 839,940		$ 36	$ 88,500	$ 1,038,324		$ (286,920)

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, 2017	Dec. 31, 2015
Successor
Net income (loss)	$ (333,982)		$ 47,062
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities
Provision for doubtful accounts	(13,166)		406
Depreciation, depletion and amortization	39,983		131,887
Impairment	319,087		4,019
Gain on reorganization items, net	0		0
Debt issuance costs amortization	0		430
Amortization of discount, net of premium, on debt	(81)		(330)
Gain on extinguishment of debt	0		0
Write off of debt issuance costs	0		0
(Gain) loss on debt derivatives	0		0
Cash paid for early conversion of convertible notes	0		0
(Gain) loss on derivative contracts	25,652		(24,090)
Cash received on settlement of derivative contracts	7,698		7,260
Loss on settlement of contract	0		0
Cash paid on settlement of contract	0		0
Stock-based compensation	6,250		15,750
Other	717		344
Changes in operating assets and liabilities increasing (decreasing) cash
Deconsolidation of noncontrolling interest	0		0
Receivables	12,872		115
Prepaid expenses	(1,079)		127
Other current assets	(260)		191
Other assets and liabilities, net	1,505		4,186
Accounts payable and accrued expenses	990		(2,199)
Asset retirement obligations	(591)		(3,979)
Net cash provided by (used in) operating activities	65,595		181,179
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures for property, plant and equipment	(51,676)		(219,246)
Acquisitions of assets	0		(48,312)
Proceeds from sale of assets	11,841		21,834
Net cash used in investing activities	(39,835)		(245,724)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from borrowings	0		0
Repayments of borrowings	(414,954)		0
Debt issuance costs	0		(1,488)
Proceeds from building mortgage	0		0
Payment of mortgage proceeds and cash recovery to debt holders	0		0
Noncontrolling interest distributions	0		0
Cash paid for tax withholdings on vested stock awards	(110)		(6,730)
Dividends paid—preferred	0		0
Other	3		0
Net cash (used in) provided by financing activities	(415,061)		(8,218)
NET (DECREASE) INCREASE IN CASH, CASH EQUIVALENTS and RESTRICTED CASH	(389,301)		(72,763)
CASH, CASH EQUIVALENTS and RESTRICTED CASH, beginning of year	563,372		174,071
CASH, CASH EQUIVALENTS and RESTRICTED CASH, end of year	174,071	$ 563,372	$ 101,308
Predecessor
Net income (loss)		1,440,797		$ (4,321,051)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities
Provision for doubtful accounts		16,704		0
Depreciation, depletion and amortization		112,301		371,772
Impairment		718,194		4,534,689
Gain on reorganization items, net		(2,442,436)		0
Debt issuance costs amortization		4,996		11,884
Amortization of discount, net of premium, on debt		2,734		3,130
Gain on extinguishment of debt		(41,179)		(641,131)
Write off of debt issuance costs		0		7,108
(Gain) loss on debt derivatives		(1,324)		10,377
Cash paid for early conversion of convertible notes		(33,452)		(32,741)
(Gain) loss on derivative contracts		4,823		(73,061)
Cash received on settlement of derivative contracts		72,608		327,702
Loss on settlement of contract		90,184		50,976
Cash paid on settlement of contract		(11,000)		(24,889)
Stock-based compensation		9,075		18,380
Other		(3,260)		2,842
Changes in operating assets and liabilities increasing (decreasing) cash
Deconsolidation of noncontrolling interest		(9,654)		0
Receivables		36,116		201,907
Prepaid expenses		(5,681)		1,148
Other current assets		(181)		12,710
Other assets and liabilities, net		(7,542)		2,239
Accounts payable and accrued expenses		(3,595)		(86,470)
Asset retirement obligations		(61,305)		(3,984)
Net cash provided by (used in) operating activities		(112,077)		373,537
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures for property, plant and equipment		(186,452)		(879,201)
Acquisitions of assets		(1,328)		(216,943)
Proceeds from sale of assets		20,090		56,504
Net cash used in investing activities		(167,690)		(1,039,640)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from borrowings		489,198		2,065,000
Repayments of borrowings		(74,243)		(939,466)
Debt issuance costs		(333)		(53,244)
Proceeds from building mortgage		26,847		0
Payment of mortgage proceeds and cash recovery to debt holders		(33,874)		0
Noncontrolling interest distributions		0		(138,305)
Cash paid for tax withholdings on vested stock awards		(44)		(3,535)
Dividends paid—preferred		0		(11,262)
Other		0		1,250
Net cash (used in) provided by financing activities		407,551		920,438
NET (DECREASE) INCREASE IN CASH, CASH EQUIVALENTS and RESTRICTED CASH		127,784		254,335
CASH, CASH EQUIVALENTS and RESTRICTED CASH, beginning of year	$ 563,372	435,588		181,253
CASH, CASH EQUIVALENTS and RESTRICTED CASH, end of year		$ 563,372		$ 435,588

Chapter 11 Bankruptcy

Chapter 11 Bankruptcy	12 Months Ended
	Dec. 31, 2017
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 “First Lien Exit Facility”). Refer to Note 12 for additional information. • Cash Collateral Account. The Company deposited $50.0 million of cash in an account controlled by the administrative agent to the First Lien Exit Facility (the “Cash Collateral Account”). This deposit was released to the Company in February 2017 in conjunction with the refinancing of the First Lien Exit Facility. • 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 “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 “Convertible Notes”), which mandatorily converted into 14.1 million shares of Common Stock upon the refinancing of the First Lien Exit Facility in February 2017. Refer to Note 12 and Note 16 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 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 12 and Note 16 for additional information. • Building Note . The Building Note with a principal amount of $35.0 million ( $36.6 million fair value on the Emergence Date), 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 Senior Unsecured Notes. Proceeds received from the Building Note were subsequently remitted to unsecured creditors on the Emergence Date in accordance with the Plan. Refer to Note 12 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 16 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 stoc k 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 Building Note (36,610 ) Less: Asset retirement obligation (92,412 ) Less: Fair value of First Lien Exit Facility (414,954 ) Less: Fair value of 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 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 Building Note, $281.8 million of the Convertible Notes, and the $415.0 million drawn on the 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 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 - Common Stock 575,144 Additional paid in capital - premium on 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 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 Convertible Notes of $445.7 million and the principal value of the 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 7 . 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 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 Convertible Notes issued (281,780 ) Gain on reorganization items, net $ 2,430,599

Fresh Start Accounting

Fresh Start Accounting	12 Months Ended
	Dec. 31, 2017
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 “First Lien Exit Facility”). Refer to Note 12 for additional information. • Cash Collateral Account. The Company deposited $50.0 million of cash in an account controlled by the administrative agent to the First Lien Exit Facility (the “Cash Collateral Account”). This deposit was released to the Company in February 2017 in conjunction with the refinancing of the First Lien Exit Facility. • 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 “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 “Convertible Notes”), which mandatorily converted into 14.1 million shares of Common Stock upon the refinancing of the First Lien Exit Facility in February 2017. Refer to Note 12 and Note 16 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 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 12 and Note 16 for additional information. • Building Note . The Building Note with a principal amount of $35.0 million ( $36.6 million fair value on the Emergence Date), 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 Senior Unsecured Notes. Proceeds received from the Building Note were subsequently remitted to unsecured creditors on the Emergence Date in accordance with the Plan. Refer to Note 12 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 16 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 stoc k 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 Building Note (36,610 ) Less: Asset retirement obligation (92,412 ) Less: Fair value of First Lien Exit Facility (414,954 ) Less: Fair value of 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 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 Building Note, $281.8 million of the Convertible Notes, and the $415.0 million drawn on the 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 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 - Common Stock 575,144 Additional paid in capital - premium on 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 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 Convertible Notes of $445.7 million and the principal value of the 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 7 . 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 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 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, 2017
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 North Park Basin regions of the United States. The Company’s North Park Basin properties were acquired during the fourth quarter of 2015. Principles of Consolidation. The consolidated financial statements include the accounts of the Company and its wholly owned or majority owned subsidiaries. During the year ended December 31, 2015, 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 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 years ended December 31, 2017 , and 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; the carrying value of unevaluated oil and natural gas properties; 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 collectibility 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 8 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 7 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 7 . 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 13 for further discussion of the Company’s derivatives. Oil and Natural Gas Operations. The Company uses the full cost method to account for its oil and natural gas properties. Under full cost accounting, all costs directly associated with the acquisition, exploration and development of oil, natural gas and NGL reserves are capitalized into a full cost pool. These capitalized costs include costs of unproved properties and internal costs directly related to the Company’s acquisition, exploration and development activities and capitalized interest. The Successor Company capitalized internal costs of $14.8 million and $4.0 million during the year ended December 31, 2017 and the Successor 2016 Period, respectively, and the Predecessor Company capitalized internal costs of $22.7 million and $45.1 million to the full cost pool during the Predecessor 2016 Period and the year ended December 31, 2015 , 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 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 10 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 year ended December 31, 2017 and the Successor 2016 Period, the Company did not capitalize any interest costs. During the Predecessor 2016 Period and the year ended December 31, 2015 , the Company capitalized interest of approximately $2.2 million and $10.8 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 in 2015 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 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 are the timing of settlement and changes in the legal, regulatory, environmental and political environments, which are subject to change. See Note 14 for further discussion of the Company’s asset retirement obligations. 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 $29.1 million and $7.4 million of transportation costs as a reduction from revenues in the year ended December 31, 2017 and the Successor 2016 Period, respectively, versus the presentation of $26.2 million and $45.3 million , respectively, of these costs as production expenses in the Predecessor 2016 Period and the year ended December 31, 2015, respectively. 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 more or less than 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 $1.6 million and $1.7 million at December 31, 2017 and 2016 , respectively. The Company includes the gas imbalance positions in other long-term obligations in the consolidated balance sheets. During the year ended December 31, 2015, 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 year ended December 31, 2015. 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 year ended December 31, 2015. 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, during the Successor 2016 Period, the Company assumed the conversion of the Convertible Notes to common stock and determined if it was more dilutive than including the expense associated with the Convertible Notes in the computation of income available to common stockholders during the period the Convertible Notes were outstanding. 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 20 for the Company’s earnings per share calculation. Commitments and Contingencies. Liabilities for loss contingencies arising from claims, assessments, litigation or other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated. Environmental expenditures are expensed or capitalized, as appropriate, depending on future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed. Environmental liabilities related to future costs are recorded on an undiscounted basis when assessments and/or remediation activities are probable and costs can be reasonably estimated. See Note 15 for discussion of the Company’s commitments and contingencies. Concentration of Risk. All of the Company’s commodity derivative transactions have been carried out in the over-the-counter market. The entry into derivative transactions in the over-the-counter market involves the risk that the counterparties may be unable to meet the financial terms of the transactions. The counterparties for all of the Company’s commodity derivative transactions have an “investment grade” credit rating. The Company monitors on an ongoing basis the credit ratings of its commodity derivative counterparties and considers its counterparties’ credit default risk ratings in determining the fair value of its commodity derivative contracts. The Company’s commodity derivative contracts are with multiple counterparties to minimize its exposure to any individual counterparty. A default by the Company under its credit facility constitutes a default under its commodity derivative contracts with counterparties that are lenders under the credit facility. The Company does not require collateral or other security from counterparties to support commodity derivative instruments. The Company has master netting agreements with all of its commodity derivative counterparties, which allow the Company to net its commodity derivative assets and liabilities 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 credit facility can be offset against amounts owed, if any, to such counterparty under the Company’s credit facility. The Company operates a substantial portion of its oil and natural gas properties. As the operator of a property, the Company makes full payment for costs associated with the property and seeks reimbursement from the other working interest owners in the property for their share of those costs. The Company’s joint interest partners consist primarily of independent oil and natural gas producers. If the oil and natural gas exploration and production industry in general was adversely affected, the ability of the joint interest partners to reimburse the Company could be adversely affected. The purchasers of the Company’s oil, natural gas and NGL production consist primarily of independent marketers, major oil and natural gas companies and gas pipeline companies. 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 December 31, 2017 - Successor Targa Pipeline Mid-Continent West OK LLC $ 144,583 40.5 % Plains Marketing, L.P. $ 117,927 33.0 % 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 % Recent Accounting Pronouncements. The Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“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 adopted the ASU on April 1, 2017. The guidance had no impact on the consolidated financial statements and related disclosures. The FASB Issued ASU 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business,” which provides a new framework for determining whether transactions should be accounted for as acquisitions (or disposals) of assets or as a business. The ASU is effective for the Company on January 1, 2018, and amendments should be applied prospectively on and after January 1, 2018. Early application is permitted for transactions for which the acquisition date occurs before the issuance date or effective date of the amendments, only when the transaction has not been reported in financial statements that have been issued or made available for issuance and for transactions in which a subsidiary is deconsolidated or a group of assets is derecognized that occur before the issuance date or effective date of the amendments, only when the transaction has not been reported in the financial statements that have been issued or made available for issuance. The Company applied this ASU for transactions effective after April 1, 2017 meeting the early application provisions above. The guidance had no impact to the Company’s consolidated financial statements and related disclosures upon adoption. The FASB issued ASU 2017-09, “Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting,” which provides guidance on determining which changes to the terms and conditions of share-based payment awards require an entity to apply modification accounting. The amendments in this ASU are effective for the Company on January 1, 2018, with early adoption permitted in any interim period. The ASU should be applied prospectively to an award modified on or after the adoption date. The Company early adopted this ASU on July 1, 2017. The guidance had no impact on the consolidated financial statements and related disclosures. The FASB issued ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” which outlines a single comprehensive model for entities to use in accounting for revenue arising 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 adopted Topic 606 on

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2017
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 Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Supplemental Disclosure of Cash Flow Information Cash paid for reorganization items $ — $ — $ (55,606 ) $ — Cash paid for interest, net of amounts capitalized $ (2,438 ) $ (1,183 ) $ (104,609 ) $ (296,386 ) Cash (paid) received for income taxes $ 4,348 $ — $ (28 ) $ (88 ) 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 $ (28,999 ) $ 10,630 $ 25,045 $ 177,586 Equity issued for debt $ (268,779 ) $ (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 )

Recent Transactions

Recent Transactions	12 Months Ended
	Dec. 31, 2017
Extractive Industries [Abstract]
Recent Transactions	Recent Transactions In the third quarter of 2017, the Company entered into a $200.0 million drilling participation agreement with a Counterparty to jointly develop new horizontal wells on a wellbore only basis within certain dedicated sections of its undeveloped leasehold acreage within the Meramec formation in Major and Woodward Counties in Oklahoma (the “NW STACK”). Under this agreement, the Counterparty is paying 90% of the net exploration and development costs, up to $100.0 million in the first tranche, in exchange for an initial 80% net working interest in each new well, subject to certain reversionary hurdles, as shown in the table below. As a result, the Company is receiving a 20% net working interest after funding 10% of the exploration and development costs related to the subject wells. This will allow the Company to spend minimal additional capital while accelerating the delineation of its position in the NW STACK, realizing further efficiencies and holding additional acreage by production, potentially adding reserves. The Company operates all of the wells developed under this agreement and will retain sole discretion as to the number, location and schedule of wells drilled. The Counterparty will also have the option to fund a second $100.0 million tranche, subject to mutual agreement. Development Costs and Working Interest (“WI”) Structure Counterparty SandRidge Development Costs 90% of Costs 10% of Costs Initial Working Interest 80% of WI 20% of WI Reversion If Counterparty Achieves 10% IRR 35% of WI 65% of WI Reversion If Counterparty Achieves 15% IRR 11% of WI 89% of WI

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2017
Acquisitions And Dispositions [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures Successor Acquisitions and Divestitures 2017 Acquisitions Acquisition of Properties. On February 10, 2017, the Company acquired assets consisting of approximately 13,000 net acres in Woodward County, Oklahoma for approximately $47.8 million in cash, net of post-closing adjustments. Also included in the acquisition were working interests in four wells previously drilled on the acreage. 2017 Divestitures 2017 Property Divestitures. In 2017, the Company divested various non-core oil and natural gas properties for approximately $17.1 million in cash. All of these divestitures were accounted for as adjustments to the full cost pool with no gain or loss recognized. Predecessor Acquisitions and Divestitures 2016 Divestiture Divestiture of West Texas Overthrust Properties and Release from Treating Agreement. In January 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 North Park Basin Properties. In December 2015, the Company acquired approximately 135,000 net acres in the North Park Basin 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

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2017
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 levels of the fair value hierarchy noted below. The carrying values of cash, restricted cash, accounts receivable, prepaid expenses, other current assets, accounts payable and accrued expenses and other current liabilities included in the unaudited condensed consolidated balance sheets approximated fair value at December 31, 2017 , and December 31, 2016 . As a result, these financial assets and liabilities are not discussed below. The fair values of property, plant and equipment and related impairments, which are calculated using Level 3 inputs, are discussed in Note 9 . 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 Level 1 and Level 2 of the hierarchy as of December 31, 2017 and 2016 , 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 of $5.1 million and $2.8 million are included in other current assets at December 31, 2017 and December 31, 2016 , respectively, and investments of $4.8 million are included in other assets at December 31, 2016 , in the accompanying consolidated balance sheets. The Company’s non-qualified deferred compensation plan was terminated and all remaining investment balances were distributed to participants in January 2018. 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 6 . The PGC Senior Secured Notes were issued at a substantial discount 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 prepayment 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 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 Predecessor 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 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, 2017 - Successor Fair Value Measurements Netting(1) Assets/Liabilities at Fair Value Level 1 Level 2 Level 3 Assets Commodity derivative contracts $ — $ 5,582 $ — $ (4,272 ) $ 1,310 Investments $ 5,072 $ — $ — $ — $ 5,072 $ 5,072 $ 5,582 $ — $ (4,272 ) $ 6,382 Liabilities Commodity derivative contracts $ — $ 18,467 $ — $ (4,272 ) $ 14,195 $ — $ 18,467 $ — $ (4,272 ) $ 14,195 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 ____________________ (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 Predecessor Company’s Level 3 fair value measurements for debt holder conversion features (in thousands): Predecessor Period from January 1, 2016 through October 1, 2016 Beginning balance $ 29,355 Gain on derivative holder conversion feature (880 ) Conversions (21,194 ) Write off of derivative holder conversion feature to reorganization items (7,281 ) Ending level 3 debt holder conversion feature balance $ — 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, 2017 , 2016 and 2015 , 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 measured the fair value of its previously outstanding non-interest bearing 0.00% Convertible Senior Subordinated Notes due 2020, (the “Convertible Notes”) using pricing that was readily available in the public market. The Successor Company measures the fair value of its $35.0 million initial principal note, as amended in February 2017, which is secured by first priority mortgages on the Company’s real estate in Oklahoma City, Oklahoma (the “Building Note”) using a discounted cash flow analysis, which is classified as a Level 2 input in the fair value hierarchy. The estimated fair values and carrying values of the Company’s long-term debt are as follows (in thousands): December 31, 2017 December 31, 2016 Fair Value Carrying Value Fair Value Carrying Value Convertible Notes $ — $ — $ 334,800 $ 268,780 Building Note $ 42,526 $ 37,502 $ 40,608 $ 36,528 See Note 12 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 10

Accounts Receivable

Accounts Receivable	12 Months Ended
	Dec. 31, 2017
Receivables [Abstract]
Accounts Receivable	Accounts Receivable A summary of accounts receivable is as follows (in thousands): December 31, 2017 2016 Oil, natural gas and NGL sales $ 34,570 $ 42,631 Joint interest billing 26,496 17,338 Oil and natural gas services 639 736 Other 10,846 14,272 Total accounts receivable 72,551 74,977 Less: allowance for doubtful accounts (1,274 ) (880 ) Total accounts receivable, net $ 71,277 $ 74,097 The following table presents the balance and activity in the allowance for doubtful accounts for the year ended December 31, 2017 , the Successor 2016 Period, the Predecessor 2016 Period and year ended December 31, 2015 (in thousands): Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Beginning balance $ 880 $ — $ 4,847 $ 7,083 Additions charged to costs and expenses(1) 397 880 16,695 1,320 Deductions(2) (3 ) — (751 ) (3,556 ) Impact of fresh start accounting — — (20,791 ) — Ending balance $ 1,274 $ 880 $ — $ 4,847 ____________________ (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 the write-off of receivables and collections of amounts for which an allowance had previously been established. Deductions in 2016 are primarily due to the write-off of receivables in conjunction with a lawsuit settlement and deductions in 2015

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment consists of the following (in thousands): December 31, 2017 2016 Oil and natural gas properties Proved $ 1,056,806 $ 840,201 Unproved 100,884 74,937 Total oil and natural gas properties 1,157,690 915,138 Less accumulated depreciation, depletion and impairment (460,431 ) (353,030 ) Net oil and natural gas properties capitalized costs 697,259 562,108 Land 4,500 5,100 Electrical infrastructure 131,010 130,242 Non-oil and natural gas equipment 26,809 35,768 Buildings and structures 79,548 88,603 Total 241,867 259,713 Less accumulated depreciation and amortization (15,886 ) (3,889 ) Other property, plant and equipment, net 225,981 255,824 Total property, plant and equipment, net $ 923,240 $ 817,932 The net carrying value of the Company’s oil and natural gas properties was reduced by $319.1 million during the Successor 2016 Period, $657.4 million during the Predecessor 2016 Period and $4.5 billion during 2015, as a result of quarterly full cost ceiling analyses in the respective periods. No full cost ceiling impairments were recorded in the 2017 period. See Note 10 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 $7.92 per Boe in 2017 , $8.31 per Boe for the Successor 2016 Period, $6.05 per Boe in the Predecessor 2016 Period and $10.81 per Boe in 2015 . The Company has approximately $10.6 million in assets classified as held for sale in the other current assets line of the accompanying consolidated balance sheet at December 31, 2017. Approximately $9.3 million of this total is related to one of the Company’s properties located in downtown Oklahoma City, OK, which was classified as held for sale in the fourth quarter of 2017 and is expected to be sold during the first half of 2018. The remaining balance largely consists of the Company’s remaining drilling and oilfield services assets. These assets had a carrying value of $6.9 million which exceeded the net realizable value of $2.9 million determined by expected sales prices obtained from third parties. As a result, the Company recorded an impairment of $4.0 million for the year ended December 31, 2017 . The Company disposed of approximately $1.7 million of these assets during the year ended December 31, 2017 , and recorded an insignificant gain on sale of assets which is included in other operating expenses in the accompanying consolidated statement of operations. The Company expects to dispose of the majority of the remaining assets within the next year. Costs Excluded from Amortization The following table summarizes the costs, by year incurred, related to unproved properties, which were excluded from oil and natural gas properties subject to amortization at December 31, 2017 (in thousands): Year Cost Incurred Total 2017 2016 2015 2014 and Prior Property acquisition $ 96,450 $ 42,827 $ 15,610 $ 19,481 $ 18,532 Exploration 4,434 1,904 678 1,453 399 Total costs incurred $ 100,884 $ 44,731 $ 16,288 $ 20,934 $ 18,931 The Company expects to complete the majority of the evaluation activities within 10

Impairment

Impairment	12 Months Ended
	Dec. 31, 2017
Asset Impairment Charges [Abstract]
Impairment	Impairment As deemed necessary based on events in 2017 , 2016 and 2015 , 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 Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Full cost pool ceiling limitation(1)(2) $ — $ 319,087 $ 657,392 $ 4,473,787 Drilling assets(3)(4) 4,019 — 3,511 37,646 Electrical infrastructure assets(5) — — 55,600 — Midstream assets(6) — — 1,691 7,148 Other(7) — — — 16,108 $ 4,019 $ 319,087 $ 718,194 $ 4,534,689 ____________________ (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 recorded in the year ended 2017 reflects the write-down of remaining drilling and oilfield services assets classified as held for sale to net realizable value. (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. (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 year ended December 31, 2015 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

Accounts Payable and Accrued Ex

Accounts Payable and Accrued Expenses	12 Months Ended
	Dec. 31, 2017
Payables and Accruals [Abstract]
Accounts Payable and Accrued Expenses	Accounts Payable and Accrued Expenses Accounts payable and accrued expenses consist of the following (in thousands): December 31, 2017 2016 Accounts payable and other accrued expenses $ 94,406 $ 65,408 Accrued interest 1,385 648 Production payable 18,059 16,011 Payroll and benefits 21,475 33,606 Drilling advances 3,830 844 Total accounts payable and accrued expenses $ 139,155 $ 116,517

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2017
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt consists of the following (in thousands): December 31, December 31, 2017 2016 Credit facility $ — $ — Convertible Notes — 268,780 Building Note 37,502 36,528 Total debt 37,502 305,308 Less: current maturities of long-term debt — — Long-term debt $ 37,502 $ 305,308 On the Emergence Date, the Predecessor Company’s outstanding debt was canceled. See Note 1 for additional information regarding the bankruptcy proceedings. Credit Facility. On February 10, 2017, the $425.0 million reserve-based revolving credit facility (the “First Lien Exit Facility”) was refinanced and replaced by a new $600.0 million credit facility (the “credit facility”). The borrowing base under the credit facility is $425.0 million . This borrowing base was reconfirmed during the October 2017 semi-annual redetermination. The next borrowing base redetermination is scheduled for April 1, 2018. The credit facility matures on March 31, 2020. The outstanding borrowings under the credit facility bear interest based on 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. 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 credit facility. The Company has the right to prepay loans under the credit facility at any time without a prepayment penalty, other than customary “breakage” costs with respect to LIBOR loans. Upon refinancing of the First Lien Exit Facility, $50.0 million maintained in a restricted cash collateral account, as required by the terms of the First Lien Exit Facility, was released to the Company. The credit facility is secured by (i) first-priority mortgages on at least 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 substantially all of the capital stock owned by each credit party and equity interests in the Royalty Trusts that are owned by a credit party and (iii) a first-priority perfected security interest in substantially all the cash, cash equivalents, deposits, securities and other similar accounts, and 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). Beginning with the quarter ended June 30, 2017, the credit facility requires the Company to maintain (i) a maximum consolidated total net leverage ratio, measured as of the end of any fiscal quarter, of no greater than 3.50 to 1.00 and (ii) a minimum consolidated interest coverage ratio, measured as of the end of any fiscal quarter, of no less than 2.25 to 1.00. These financial covenants are subject to customary cure rights. The Company was in compliance with all applicable financial covenants under the credit facility as of December 31, 2017 . The credit facility also contains customary affirmative and negative covenants, including as to 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 was in compliance with these covenants as of December 31, 2017 . The credit facility includes events of default relating to customary matters, including, among other things, nonpayment of principal, interest or other amounts; violation of covenants; incorrectness of representations and warranties in any material respect; cross-payment default and cross acceleration with respect to indebtedness in an aggregate principal amount of $25.0 million or more; bankruptcy; judgments involving a liability of $25.0 million or more that are not paid; and ERISA events. Many events of default are subject to customary notice and cure periods. The Company had no amounts outstanding under the credit facility at December 31, 2017 and $6.7 million in outstanding letters of credit, which reduce availability under the credit facility on a dollar-for-dollar basis. First Lien Exit Facility. On the Emergence Date, the Company entered into the First Lien Exit Facility with the lenders party thereto and Royal Bank of Canada, as administrative agent and issuing lender. The borrowing base under the First Lien Exit Facility was $425.0 million . The First Lien Exit Facility was set to mature on February 4, 2020. The outstanding borrowings under the First Lien Exit Facility bore 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 was payable quarterly in arrears and interest on LIBOR borrowings was payable every one, two, three or six months, at the election of the Company. Quarterly, the Company was committed to pay fees assessed at annual rates of 0.50% on any available portion of the First Lien Exit Facility. The Company had the right to prepay loans under the First Lien Exit Facility at any time without a prepayment penalty, other than customary “breakage” costs with respect to LIBOR loans. The First Lien Exit Facility contained certain financial covenants and customary affirmative and negative covenants. The Company was in compliance with all applicable covenants through the date it was refinanced. 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 Convertible Notes, which did not bear regular interest and were set to mature and mandatorily convert into shares of common stock in the Successor Company (“the Common Stock”) on October 4, 2020, unless repurchased, redeemed or converted prior to that date. The Convertible Notes were recorded at their fair value of $445.7 million upon implementation of fresh start accounting. The resulting premium of $163.9 million was deemed significant to the principal amount of the Convertible Notes, and as such, was recorded in additional paid in capital in the condensed consolidated balance sheet at December 31, 2016. The Company’s obligations pursuant to the Convertible Notes were fully and unconditionally guaranteed, jointly and severally, by each of the guarantors of the First Lien Exit Facility. The Convertible Notes were initially convertible at a conversion rate of 0.05330841 shares of Common Stock per $1.00 principal amount of Convertible Notes, which represented, in the aggregate, approximately 15.0 million shares of common stock. The conversion rate for the New Convertible Notes was subject to customary anti-dilution adjustments. The Convertible Notes were convertible at the option of the holders at any time up to, and including, the business day immediately preceding the maturity date. Between the Emergence Date and December 31, 2016, approximately $13.0 million in aggregate principal amount of the Convertible Notes was converted into approximately 0.7 million shares of Common Stock following delivery of voluntary conversion notices by the holders of those Convertible Notes. Additionally, during the period from January 1, 2017 to February 9, 2017, approximately $5.1 million in aggregate principal amount of the Convertible Notes was converted into approximately 0.3 million shares of Common Stock following delivery of voluntary conversion notices by the holders of those Convertible Notes. The remaining $263.7 million par value of outstanding Convertible Notes mandatorily converted into 14.1 million shares of Common Stock upon the refinancing of the First Lien Exit Facility on February 10, 2017, after the determination by the Successor Company’s board of directors in good faith that: (a) the refinancing provided for terms that were materially more favorable to the Company and (b) causing a conversion was not the primary purpose of the refinancing. Building Note . As discussed in Note 1 , on the Emergence Date, the Company entered into the Building Note, which had an initial principal amount of $35.0 million . The Building Note was recorded at a fair value of $36.6 million upon implementation of fresh start accounting. The resulting premium is being amortized to interest expense over the term of the Building Note. Interest is payable on the 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. Interest costs were paid in kind and added to the Building Note principal from the Emergence Date through May 11, 2017, which was 90 days after the refinancing or repayment of the First Lien Exit Facility. Interest became payable thereafter in cash. The Building Note matures on October 2, 2021 and became prepayable in whole or in part without premium or penalty upon the refinancing of the First Lien Exit Facility. Net proceeds of $26.8 million received from the sale of the Building Note were subsequently remitted to unsecured creditors on the Emergence Date in accordance with the Plan. Maturities of Long-Term Debt As of December 31, 2017 , $36.3 million

Derivatives

Derivatives	12 Months Ended
	Dec. 31, 2017
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. The Company has not designated any of its derivative contracts as hedges for accounting purposes and records all derivative contracts at fair value with changes in derivative contract fair values recognized in (gain) loss on derivative contracts in the condensed consolidated statements of operations. 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. Commodity derivative contracts are settled on a monthly basis. On a quarterly basis, the commodity derivative contract valuations are adjusted to the mark-to-market valuation. At December 31, 2017 , 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 Successor Company recorded (gain) loss on commodity derivative contracts of $(24.1) million and $25.7 million for the year ended December 31, 2017 and the Successor 2016 Period, respectively, as reflected in the accompanying consolidated statements of operations, which includes net cash receipts upon settlement of $7.3 million and $7.7 million , respectively. The Predecessor Company recorded loss (gain) on commodity derivative contracts of $4.8 million and $(73.1) million for the Predecessor 2016 Period and the year ended December 31, 2015 , respectively, as reflected in the accompanying consolidated statements of operations, which includes net cash receipts upon settlement of $72.6 million and $327.7 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. Derivatives Agreements with Royalty Trusts. During the year ended December 31, 2015, the Company was party to derivatives agreements with the Mississippian Trust I, Permian Trust and Mississippian Trust II to provide each of the Royalty Trusts 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, 2017 , the counterparties to the Company’s open commodity derivative contracts consisted of seven financial institutions, all of which are also lenders under the Company’s credit facility. The Company is not required to post additional collateral under its commodity derivative contracts as all of the counterparties to the Company’s commodity derivative contracts share in the collateral supporting the Company’s credit 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 credit facility as of December 31, 2017 and the First Lien Exit Facility as of December 31, 2016 (in thousands): December 31, 2017 Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount Assets Derivative contracts - current $ 5,582 $ (4,272 ) $ 1,310 $ — $ 1,310 Derivative contracts - noncurrent — — — — — Total $ 5,582 $ (4,272 ) $ 1,310 $ — $ 1,310 Liabilities Derivative contracts - current $ 14,899 $ (4,272 ) $ 10,627 $ (10,627 ) $ — Derivative contracts - noncurrent 3,568 — 3,568 (3,568 ) — Total $ 18,467 $ (4,272 ) $ 14,195 $ (14,195 ) $ — December 31, 2016 Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount 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 ) $ — At December 31, 2017 , the Company’s open commodity derivative contracts consisted of the following: Oil Price Swaps Notional (MBbls) Weighted Average Fixed Price January 2018 - December 2018 3,464 $ 55.08 January 2019 - December 2019 1,460 $ 53.34 Natural Gas Price Swaps Notional (MMcf) Weighted Average Fixed Price January 2018 - December 2018 17,300 $ 3.16 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): December 31, December 31, Type of Contract Balance Sheet Classification 2017 2016 Derivative assets Oil price swaps Derivative contracts - current $ — $ — Natural gas price swaps Derivative contracts - current 5,582 — Oil price swaps Derivative contracts - noncurrent — — Natural gas price swaps Derivative contracts - noncurrent — — Derivative liabilities Oil price swaps Derivative contracts - current (14,899 ) (13,395 ) Natural gas price swaps Derivative contracts - current — (14,143 ) Oil price swaps Derivative contracts - noncurrent (3,568 ) (2,105 ) Natural gas price swaps Derivative contracts - noncurrent — (71 ) Total net derivative contracts $ (12,885 ) $ (29,714 ) See Note 7

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The following table presents the balance and activity of the Company’s asset retirement obligations (in thousands): Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Beginning balance $ 106,481 $ 92,413 $ 103,578 $ 54,402 Liability incurred upon acquiring and drilling wells 1,336 121 505 1,662 Revisions in estimated cash flows(1) (28,565 ) 12,397 — 44,060 Liability settled or disposed in current period(2) (11,308 ) (540 ) (36,979 ) (1,023 ) Accretion 9,600 2,090 4,365 4,477 Impact of fresh start accounting — — 20,944 — Ending balance 77,544 106,481 92,413 103,578 Less: current portion 41,017 66,154 65,678 8,399 Asset retirement obligations, net of current $ 36,527 $ 40,327 $ 26,735 $ 95,179 ____________________ (1) Revisions for the year ended December 31, 2017, the Successor 2016 Period and the year ended December 31, 2015 relate primarily to changes in estimated well lives and changes in oil and natural gas prices. (2) Liability settled or disposed for the Predecessor 2016 Period includes $34.1 million

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2017
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, 2017 , 2016 and 2015 . Employee termination benefits were $4.8 million for the year ended December 31, 2017 , $12.3 million for the Successor 2016 Period and $18.4 million for the Predecessor 2016 Period, primarily as a result of reductions in workforce. For the year ended December 31, 2015, employee termination benefits were $12.5 million , primarily as a result of a reduction in workforce and certain executives’ separation from employment. 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 13 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 credit facility to fund its capital expenditures. Based on its cash balances, cash flows from operating activities and net borrowing availability under the credit facility, the Company expects to be able to fund its planned capital expenditures budget, debt service requirements and working capital needs for the next year; however, if 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. Litigation and Claims. On October 14, 2016, Lisa West and Stormy Hopson filed an amended 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 amended complaint, plaintiffs asserted various tort claims seeking relief for damages, including the reimbursement of past and future earthquake insurance premiums, resulting from seismic activity allegedly caused by the defendants’ operation of wastewater disposal wells. The court dismissed the plaintiffs’ amended complaint on May 12, 2017, but permitted the plaintiffs to file a second amended complaint. On July 18, 2017, the plaintiffs filed a second amended class action complaint making allegations substantially similar to those contained in the amended complaint that was previously dismissed. An estimate of reasonably possible losses associated with this action can not be made at this time. The Company has not established any reserves relating to this action.

Equity

Equity	12 Months Ended
	Dec. 31, 2017
Equity [Abstract]
Equity	Equity Successor Equity Common Stock. As discussed in Note 1 , on the Emergence Date, the previously issued Predecessor Company common stock was canceled and an aggregate of approximately 18.9 million shares of Common Stock, par value $0.001 per share, was issued to the holders of allowed claims, as defined in the Plan. Approximately 0.4 million shares of Common Stock were reserved for future distributions under the Plan and approximately 0.1 million of the reserved shares were issued during the year ended December 31, 2017 . Additionally, from the Emergence Date through February 9, 2017, voluntary conversions of Convertible Notes resulted in the issuance of approximately 1.0 million shares of Common Stock. The remaining balance of Convertible Notes converted to 14.1 million shares of Common Stock upon refinancing of the First Lien Exit Facility. See Note 12 for further discussion of the Convertible Notes. Shareholder Rights Plan. On November 26, 2017, the Company’s Board adopted a short-term shareholder rights plan, which was further amended on January 22, 2018, (the “Rights Plan”). The Rights Plan will be triggered only if a person or group of persons exceeds beneficial ownership of 15% or more of the Company’s common stock. The Company intends to recommend the ratification of the Rights Plan for approval by its shareholders at the Company’s 2018 annual meeting of shareholders. If ratified by the shareholders, the Rights Plan will expire on November 26, 2018. If the Rights Plan is not ratified, then it will terminate and cease to be effective. 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 were issued immediately upon emergence, and 2.1 million Series B Warrants, 1.9 million of which were issued immediately upon emergence. Warrants not issued immediately upon emergence were held in reserve for the future settlement of general unsecured claims under the Plan. The Warrants were initially exercisable for one share of 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. Approximately 0.1 million Series A Warrants and an insignificant amount of Series B Warrants were issued under the Plan during the year ended December 31, 2017 . 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. Shares Withheld for Taxes. 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. Successor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Number of shares withheld for taxes 349 5 Value of shares withheld for taxes $ 6,730 $ 110 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 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% and 7.0% convertible perpetual preferred stock are as follows (in thousands): Predecessor Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 8.5% Convertible perpetual preferred stock Dividends paid in cash $ — $ 11,262 Dividends satisfied in shares of common stock(1) $ — $ 11,262 Accrued dividends at period end $ — $ 8,447 Dividends in arrears $ 11,262 $ — 7.0% Convertible perpetual preferred stock Dividends paid in cash $ — $ — Dividends satisfied in shares of common stock(2) $ — $ 10,500 Accrued dividends at period end $ — $ 13,125 Dividends in arrears $ 21,000 $ 10,500 ____________________ (1) For the year ended December 31, 2015 , the Company paid a semi-annual dividend by issuing approximately 18.6 million shares of common stock. For purposes of the dividend payment, the value of each share issued was calculated as 95% of the average volume-weighted share price for the 15 trading day period ending July 29, 2015. Based upon the common stock’s closing price on August 17, 2015, the common stock issued had a market value of approximately $9.5 million , ( $3.58 per outstanding share at the time the dividend was paid) that resulted in a difference between the fixed rate semi-annual dividend and the value of shares issued of approximately $1.8 million , which was recorded as a reduction to preferred stock dividends in the accompanying 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 income available (loss applicable) to the Company’s common stockholders and the Company’s basic earnings (loss) per share calculation for the Predecessor 2016 Period and year ended December 31, 2015 , are presented in the accompanying consolidated statements of operations. See Note 20 for discussion of the Company’s earnings (loss) 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 . 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. The Company had 2.1 million shares of such common stock held in treasury at December 31, 2015. 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. Redemption of Senior Unsecured Notes. During the year ended December 31, 2015, the Predecessor Company issued approximately 28.0 million shares of common stock in exchange for $50.0 million in 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 17 for discussion of the Company’s share-based compensation. Shares Withheld for Taxes. 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

Share-Based Compensation	12 Months Ended
	Dec. 31, 2017
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 the Successor Company issued new Common Stock on the Emergence Date. Accordingly, the Predecessor Company's then existing share-based compensation awards were also canceled, which resulted in the recognition of $5.9 million in previously unamortized expense related to these 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. The SandRidge Energy, Inc. 2016 Omnibus Incentive Plan (the “Omnibus Incentive Plan”) became effective on the Emergence Date after the cancellation of the Predecessor Company’s share-based compensation awards. The Omnibus Incentive Plan authorizes the issuance of up to 4.6 million shares of SandRidge Common Stock. Persons eligible to receive awards under the Omnibus Incentive Plan include non-employee directors of the Company, employees of the Company or any of its affiliates, and certain consultants and advisors to the 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 Common Stock, as well as certain cash-based awards. At December 31, 2017 , the Company had restricted stock awards, performance share units and performance units outstanding under the Omnibus Incentive Plan. Forfeitures for these awards are recognized as they occur. Restricted Stock Awards. The Successor Company’s restricted stock awards are equity-classified awards and are valued based upon the market value of the Company’s Common Stock on the date of grant. 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. In 2017, awards for approximately 0.7 million shares were granted, which will vest over a period of approximately 2.5 years. The Successor Company recognized total share-based compensation expense related to its restricted stock awards of $16.6 million and $6.6 million , of which $2.0 million and $0.3 million were capitalized, for the year ended December 31, 2017 and the Successor 2016 Period, respectively. Share-based compensation expense for the year ended December 31, 2017 , includes $1.8 million for the accelerated vesting of 0.1 million restricted common stock awards. 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 Granted 671 $ 19.97 Vested (827 ) $ 23.23 Forfeited / Canceled (146 ) $ 23.52 Unvested restricted shares outstanding at December 31, 2017 1,105 $ 22.62 As of December 31, 2017 , the Successor Company’s unrecognized compensation cost related to unvested restricted stock awards was $21.4 million . The remaining weighted-average contractual period over which this compensation cost may be recognized is 1.8 years. The aggregate intrinsic value of restricted stock that vested during 2017 was approximately $16.0 million based on the stock price at the time of vesting. Performance Share Units. In February 2017, the Company granted equity-classified awards in the form of performance share units, which will vest upon completion of the stated performance period from January 1, 2017 through June 30, 2019. The performance share units will be settled in Common Stock with one share of Common Stock being issued per performance share unit up to a maximum of approximately 0.4 million shares of Common Stock, provided the required performance measures are met. The shares are valued based on the Company’s performance relative to certain performance and market conditions. For the year ended December 31, 2017 , the Successor Company recognized total share-based compensation expense related to its performance share units of $1.4 million , of which $0.2 million was capitalized. Successor Incentive-Based Compensation Performance Units. In October 2016, the Company granted liability-classified awards in the form of performance units, which will vest over a three-year period and will be settled in cash, provided the required performance measures are met. The performance units were issued at a value of $100 each and the value at vesting will be determined by annual scorecard results. At December 31, 2017 , the liability related to performance units was $3.1 million . Additionally, the Successor Company recognized total incentive-based compensation expense related to its performance units of $2.6 million , of which $0.4 million was capitalized for the year ended December 31, 2017 . 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, 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 total share-based compensation expense of $11.2 million , of which $1.7 million was capitalized, for the Predecessor 2016 Period, and $21.7 million , of which $5.9 million was capitalized for the year ended December 31, 2015 , respectively. Share-based compensation expense for the Predecessor 2016 Period includes $5.4 million for the accelerated vesting of 1.3 million

Incentive and Deferred Compensa

Incentive and Deferred Compensation Plans	12 Months Ended
	Dec. 31, 2017
Compensation Related Costs [Abstract]
Incentive and Deferred Compensation Plans	Incentive and Deferred Compensation Plans 2017 Annual Incentive Plan. The 2017 Annual Incentive Plan (“AIP”) incorporated quantitative performance measures, strategic qualitative goals and competitive target award levels for management and employees for the 2017 performance year. Potential payout percentages ranged from 0% to 200% of specified target levels based on actual performance. As of December 31, 2017, the Company had accrued approximately $10.8 million for the AIP for all employees, including an accrual for specified members of management. Payments will be made based on actual performance as determined by the Board of Directors relative to the targets specified in the plan in the first quarter of 2018. 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 and approximately $15.8 million during the first quarter of 2017. 401(k) Plan. 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 year ended December 31, 2017 , the Successor Company made matching contributions to the plan equal to 100% on the first 10% of employee deferred wages, excluding incentive compensation, totaling $3.6 million . For the Successor 2016 Period, the Successor Company made matching cash contributions to the plan equal to 100% on the first 10% of 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% of employee deferred wages for the period tot aling $4.9 million . For the year ended December 31, 2015 , the Predecessor Company made matching contributions to the plan through cash purcha ses of Predecessor Company stock equal to 100% on the first 10% of employee deferred wages. Retirement plan expense for the years ended December 31, 2015 was approximately $7.9 million . 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. Deferred Compensation Plans. The Company maintained 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 were 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 $5.1 million

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The Company’s income tax (benefit) provision consisted of the following components (in thousands): Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Current Federal $ (8,719 ) $ — $ — $ — State (30 ) 9 11 123 (8,749 ) 9 11 123 Deferred Federal — — — — State — — — — — — — — Total (benefit) provision (8,749 ) 9 11 123 Less: income tax provision attributable to noncontrolling interest — — — 90 Total (benefit) provision attributable to SandRidge Energy, Inc. $ (8,749 ) $ 9 $ 11 $ 33 A reconciliation of the (benefit) provision for income taxes at the statutory federal tax rate to the Company’s actual income tax (benefit) provision is as follows (in thousands): Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Computed at federal statutory rate $ 13,409 $ (116,891 ) $ 504,283 $ (1,512,325 ) State taxes, net of federal benefit (284 ) (3,696 ) 10,512 (19,988 ) Non-deductible expenses 1,711 144 462 816 Non-deductible debt costs — — 22,694 10,228 Stock-based compensation 1,109 306 5,884 6,700 Net effects of consolidating the non-controlling interests’ tax provisions — — — 218,196 Discharge of debt and other reorganization related items 1,018 — 359,278 — Return to provision adjustments (1) 341,681 — — — Impact of legislative changes 243,801 — — — Release of valuation allowance (8,719 ) — — — Change in valuation allowance (602,452 ) 120,144 (903,102 ) 1,296,405 Other (23 ) 2 — 1 Total (benefit) provision attributable to SandRidge Energy, Inc. $ (8,749 ) $ 9 $ 11 $ 33 ____________________ (1) Primarily related to the Company’s decision to file its 2016 income tax returns using an alternate method than previously estimated with respect to its Chapter 11 related transactions. See additional discussion with respect to Internal Revenue Code (“IRC”) Section 382 below. 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. 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. During the year ended December 31, 2017 , the Company reduced the valuation allowance associated with deferred tax assets related to alternative minimum tax (“AMT”) credits that became realizable as a result of a special tax election. Accordingly, the Company recorded an income tax benefit of $8.7 million in the year ended December 31, 2017. 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 remaining net deferred tax asset at December 31, 2017 . As of December 31, 2017 , 2016 and 2015 , the balance of the valuation allowance was $0.5 billion , $1.1 billion , and $2.0 billion , respectively. Significant components of the Company’s deferred tax assets and liabilities are as follows (in thousands): December 31, 2017 December 31, 2016 Deferred tax liabilities Investments(1) $ 171,517 $ 275,128 Total deferred tax liabilities 171,517 275,128 Deferred tax assets Property, plant and equipment 391,273 751,683 Derivative contracts 3,131 11,274 Allowance for doubtful accounts 986 1,487 Net operating loss carryforwards 217,259 527,079 Compensation and benefits 5,700 14,494 Tax Credits and other carryforwards 33,001 43,770 Asset retirement obligations 18,843 40,399 Other 2,273 4,663 Total deferred tax assets 672,466 1,394,849 Valuation allowance (500,949 ) (1,119,721 ) Net deferred tax liability $ — $ — ____________________ (1) Includes the Company’s deferred tax liability resulting from its investment in the Royalty Trusts. The “Tax Cuts and Jobs Act” (the “TCJA”) enacted in December 2017 includes significant changes to the taxation of business entities, most of which are effective for taxable years beginning after December 31, 2017. These changes include, among others, a permanent reduction to the corporate income tax rate from a maximum 35% to a flat 21% rate, expansion of expensing capital expenditures for a period of time, new limitations on the utilization of net operating losses, and limitations on the deduction of interest expense and executive compensation. Based on our analysis of the TCJA and guidance currently available we recorded an income tax expense of approximately $243.8 million in the period ended December 31, 2017, which was completely offset by a decrease in the corresponding valuation allowance. The provisional amount primarily related to the remeasurement of our gross deferred tax assets and liabilities existing at December 31, 2017 at the appropriate tax rate expected to exist at the time of their reversal. We continue to evaluate the impact of the TCJA and while adjustments to certain deferred tax assets may occur in 2018 due to additional guidance or changes in estimates, we do not expect a material adjustment to our existing net deferred tax balance. 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 a result of the Chapter 11 reorganization and related transactions, the Company experienced an ownership change within the meaning of IRC Section 382 on October 4, 2016. 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 on its tax attributes and previously planned to elect an available alternative upon filing its 2016 U.S. federal income tax return that would not subject existing tax attributes to an immediate IRC Section 382 limitation, but which would have resulted in a full limitation should a subsequent ownership change occur within two years of the emergent date ownership change. Alternatively, upon filing its 2016 U.S. federal income tax return, the Company elected a method that did subject tax attributes including net operating losses (“NOLs”) existing at October 4, 2016 to an annual limitation but provided more certainty with respect to the future availability of the Company’s existing NOLs. This limitation is expected to result in a significant portion of our NOL carryforwards expiring unused. As such, the Company’s deferred tax asset associated with NOLs and corresponding valuation allowance are materially less at December 31, 2017 compared to December 31, 2016. The election and resulting limitation did not result in an income tax expense as the Company’s net deferred tax asset had previously been reduced to zero by a valuation allowance. Additionally, the limitation did not result in a tax liability for the tax years ended December 31, 2016 or December 31, 2017. As of December 31, 2017 , the Company had approximately $4.7 million of alternative minimum tax credits available that do not expire. However, due to a special tax election available, the AMT credits are reflected as a current receivable as of December 31, 2017 . In addition, the Company had approximately $805.3 million of federal net operating loss carryovers, net of NOLs expected to expire unused due to the 2016 IRC Section 382 limitation, that expire during the years 2025 through 2037 . At December 31, 2017 and 2016 , the Company had an insignificant liability for unrecognized tax benefits. A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows (in thousands): Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Unrecognized tax benefit at January 1 $ 84 $ 81 $ 81 Changes to unrecognized tax benefits related to a prior period 2 3 — Lapse of statute of limitations (38 ) — — Unrecognized tax benefit at December 31 $ 48 $ 84 $ 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, 2017 , 2016 and 2015 . The Company expects a lapse in statute of limitation to eliminate 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 2014 to present remain open for federal examination. Additionally, tax years 2005 through 2013 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 is generally from three to five

Earnings (Loss) per Share

Earnings (Loss) per Share	12 Months Ended
	Dec. 31, 2017
Earnings Per Share [Abstract]
(Loss) Earnings per Share	Earnings (Loss) per Share As discussed in Note 1 , on the Emergence Date, the Predecessor Company’s then-authorized common stock was canceled and the new Common Stock and Warrants were issued. The following table summarizes the calculation of weighted average common shares outstanding used in the computation of diluted earnings (loss) per share: Net Income (Loss) Weighted Average Shares Earnings (Loss) Per Share (In thousands, except per share amounts) Year Ended December 31, 2017 (Successor) Basic earnings per share $ 47,062 32,442 $ 1.45 Effect of dilutive securities Restricted stock awards — 221 Performance share units(1) — — Warrants(1) — — Diluted earnings per share $ 47,062 32,663 $ 1.44 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(2) — — Warrants(2) — — Convertible Notes(3) — — 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(4) — — 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(4) — — Convertible preferred stock (5) — — Convertible senior unsecured notes(6) — — Diluted loss per share $ (3,735,495 ) 521,936 $ (7.16 ) ____________________ (1) No incremental shares of potentially dilutive performance share units or warrants were included for the year ended December 31, 2017 , as their effect was antidilutive. See Note 17 for discussion of the Company’s share and incentive-based compensation awards. (2) No incremental shares of potentially dilutive restricted stock awards or warrants were included for the Successor 2016 Period as their effect was antidilutive. (3) Potential common shares related to the 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. (4) 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. (5) Potential common shares related to the Predecessor Company’s then-outstanding 8.5% and 7.0% convertible perpetual preferred stock covering 71.2 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. (6) 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 16

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2017
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Executive Team and Organizational Restructuring. On February 8, 2018, the Company announced the departure of James Bennett, President and CEO, effective immediately, and Julian Bott, Chief Financial Officer, effective at the close of business on the date of filing this 2017 Annual Report with the SEC. Simultaneously, the Company announced the appointment of independent board member, Bill Griffin, as Interim President and Chief Executive Officer, and the appointment of Sylvia K. Barnes as an independent director, effective February 8, 2018, and the appointment of Chief Accounting Officer, Michael Johnson, as Interim Chief Financial Officer, effective upon the departure of Mr. Bott. Additionally, on February 8, 2018, the Company announced its new strategic direction, which includes implementing changes in the organizational structure and a reduction in planned 2018 capital expenditures and general and administrative expenses. Merger proposal. On February 6, 2018, the Company received an unsolicited proposal from Midstates Petroleum Company, Inc. (“Midstates”) to combine SandRidge and Midstates in an all stock merger transaction. On February 7, 2018, the Company announced that its board of directors, in consultation with independent financial and legal advisers, will carefully review and evaluate Midstates’ proposal, taking into account the Company’s current strategic plan and standalone prospects. Shareholder activism. Subsequent to the announcement of the Bonanza Creek Energy, Inc. merger in November 2017 , the Company has been actively engaged in ongoing discussions with its shareholders regarding the composition of the Company’s board of directors and the future direction of the Company. As a result of these discussions, the Company expects to incur significant additional costs related to shareholder activism including proxy fees charged by its independent financial adviser. Building Mortgage.

Supplemental Information on Oil

Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited)	12 Months Ended
	Dec. 31, 2017
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, December 31, 2017 2016 2015 Oil and natural gas properties Proved $ 1,056,806 $ 840,201 $ 12,529,681 Unproved 100,884 74,937 363,149 Total oil and natural gas properties 1,157,690 915,138 12,892,830 Less accumulated depreciation, depletion and impairment (460,431 ) (353,030 ) (11,149,888 ) Net oil and natural gas properties capitalized costs $ 697,259 $ 562,108 $ 1,742,942 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 Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Acquisitions of properties Proved $ 7,092 $ 5,142 $ 3,897 $ 35,376 Unproved 91,139 5,491 1,899 210,065 Exploration(1) 8,850 — 1,234 29,297 Development 187,264 27,429 149,924 571,562 Total cost incurred $ 294,345 $ 38,062 $ 156,954 $ 846,300 ____________________ (1) Includes 3-D seismic costs of $7.1 million for the year ended December 31, 2015 . Results of Operations for Oil and Natural Gas Producing Activities The following table presents the Company’s results of operations from oil and natural gas producing activities (in thousands), which exclude any interest costs or indirect general and administrative costs and, therefore, are not necessarily indicative of the contribution to net earnings of the Company’s operations. Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Revenues $ 356,210 $ 98,307 $ 279,971 $ 707,434 Expenses Production costs 116,372 27,640 135,715 324,141 Depreciation and depletion 118,035 36,061 90,978 324,390 Impairment — 319,087 657,392 4,473,787 Total expenses 234,407 382,788 884,085 5,122,318 Income (loss) before income taxes 121,803 (284,481 ) (604,114 ) (4,414,884 ) Income tax expense (benefit)(1) 47,722 (112,427 ) (229,986 ) (1,680,746 ) Results of operations for oil and natural gas producing activities (excluding corporate overhead and interest costs) $ 74,081 $ (172,054 ) $ (374,128 ) $ (2,734,138 ) ____________________ (1) Income tax expense (benefit) is hypothetical and is calculated by applying the Company’s statutory tax rate to income (loss) before income taxes attributable to our oil and natural gas producing activities, after giving effect to permanent differences and tax credits. 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; 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 2017 , 2016 and 2015 . 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. The remaining proved reserves were 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. 2017 Activity. During 2017, the Company recorded extensions and discoveries of 19.4 MMBoe, primarily from successful drilling in its NW STACK play in the Mid-Continent area and its North Park Basin properties, sold 1.9 MMBoe of proved reserves, and recorded upward revisions of 10.9 MMBoe, primarily as a result of significantly higher commodity prices in 2017 and minor revisions due to well performance. 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 North Park Basin 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. The summary below presents changes in the Company’s estimated reserves. Oil NGL Natural Gas Total (MBbls) (MBbls) (MMcf)(1) MBoe Proved developed and undeveloped reserves As of December 31, 2014(2) - Predecessor 126,031 91,786 1,788,233 515,856 Revisions of previous estimates (70,708 ) (37,384 ) (759,106 ) (234,610 ) Acquisitions of new reserves 22,447 2,460 15,952 27,566 Extensions and discoveries 9,741 9,257 160,865 45,809 Production (9,600 ) (5,044 ) (92,104 ) (29,995 ) As of December 31, 2015(2) - Predecessor 77,911 61,075 1,113,840 324,626 Adoption of ASU 2015-02 (6,971 ) (3,695 ) (50,508 ) (19,084 ) Revisions of previous estimates (39,973 ) (21,475 ) (415,568 ) (130,709 ) Extensions and discoveries 987 472 7,955 2,785 Sales of reserves in place (387 ) — (145,267 ) (24,598 ) Production (4,315 ) (3,358 ) (44,124 ) (15,027 ) As of October 1, 2016 - Predecessor 27,252 33,019 466,328 137,992 Revisions of previous estimates 23,978 1,139 915 25,270 Extensions and discoveries 2,868 448 10,309 5,034 Production (1,214 ) (999 ) (12,770 ) (4,341 ) As of December 31, 2016 - Successor 52,884 33,607 464,782 163,955 Revisions of previous estimates 804 2,628 44,679 10,879 Acquisitions of new reserves 18 70 683 202 Extensions and discoveries 12,446 1,914 30,080 19,373 Sales of reserves in place (204 ) (529 ) (7,055 ) (1,909 ) Production (4,157 ) (3,376 ) (44,237 ) (14,906 ) As of December 31, 2017 - Successor 61,791 34,314 488,932 177,594 Proved developed reserves As of December 31, 2014 - Predecessor 79,022 56,823 1,203,447 336,420 As of December 31, 2015 - Predecessor 48,639 51,089 964,617 260,498 As of October 1, 2016 - Predecessor 24,541 30,238 428,050 126,121 As of December 31, 2016 - Successor 25,911 29,290 393,028 120,706 As of December 31, 2017 - Successor 25,845 29,922 407,988 123,765 Proved undeveloped reserves As of December 31, 2014 - Predecessor 47,009 34,963 584,786 179,436 As of December 31, 2015 - Predecessor 29,272 9,986 149,223 64,129 As of October 1, 2016 - Predecessor 2,711 2,781 38,278 11,872 As of December 31, 2016 - Successor 26,973 4,317 71,754 43,249 As of December 31, 2017 - Successor 35,946 4,392 80,944 53,829 ____________________ (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, 2017 , 2016 , and 2015 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, December 31, 2017 2016 2015 Oil (per barrel) $ 48.47 $ 38.59 $ 45.29 NGL (per barrel) $ 20.28 $ 10.99 $ 12.68 Natural gas (per Mcf) $ 1.90 $ 1.56 $ 1.87 • 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, December 31, 2017 2016 2015 Future cash inflows from production $ 4,621,615 $ 3,136,762 $ 6,387,944 Future production costs (1,837,852 ) (1,454,798 ) (2,731,542 ) Future development costs(1) (966,203 ) (665,516 ) (838,945 ) Future income tax expenses (107 ) (142 ) (901 ) Undiscounted future net cash flows 1,817,453 1,016,306 2,816,556 10% annual discount (1,068,159 ) (577,942 ) (1,501,994 ) Standardized measure of discounted future net cash flows(2) $ 749,294 $ 438,364 $ 1,314,562 ____________________ (1) Includes abandonment costs. (2) Includes approximately $224.6 million attributable to noncontrolling interests at December 31, 2015 . 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 Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Beginning present value $ 438,364 $ 392,604 $ 1,314,562 $ 4,087,752 Changes during the year Adoption of ASU 2015-02 — — (224,965 ) — Revenues less production (239,838 ) (70,668 ) (144,256 ) (383,293 ) Net changes in prices, production and other costs 347,458 35,684 (394,173 ) (3,813,465 ) Development costs incurred 35,517 7,941 69,080 217,596 Net changes in future development costs (64,484 ) (291,232 ) 436,041 273,437 Extensions and discoveries 112,556 14,986 12,449 230,055 Revisions of previous quantity estimates 26,697 308,374 (728,254 ) (1,354,778 ) Accretion of discount 37,226 9,375 91,337 512,483 Net change in income taxes 23 — 402 1,426,333 Purchases of reserves in-place 454 — — 18,429 Sales of reserves in-place (2,977 ) — (13,314 ) — Timing differences and other(1) 58,298 31,300 (26,305 ) 100,013 Net change for the year 310,930 45,760 (921,958 ) (2,773,190 ) Ending present value(2) $ 749,294 $ 438,364 $ 392,604 $ 1,314,562 ____________________ (1) The change in timing differences and other are related to revisions in the Company’s estimated time of production and development. (2) Includes approximately $224.6 million

Quarterly Financial Results (Un

Quarterly Financial Results (Unaudited)	12 Months Ended
	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Results (Unaudited)	Quarterly Financial Results (Unaudited) The Company’s operating results for each quarter of 2017 and 2016 are summarized below (in thousands, except per share data). Successor First Quarter Second Quarter Third Quarter Fourth Quarter 2017 Total revenues $ 98,350 $ 84,851 $ 80,892 $ 93,206 Income (loss) from operations(1)(2) $ 50,780 $ 23,348 $ (16,267 ) $ (18,230 ) Net income (loss)(1)(2) $ 50,808 $ 23,499 $ (8,485 ) $ (18,760 ) Income available (loss applicable) to SandRidge Energy, Inc. common stockholders(1)(2) $ 50,808 $ 23,499 $ (8,485 ) $ (18,760 ) Income available (loss applicable) per share to SandRidge Energy, Inc. common stockholders Basic $ 1.90 $ 0.69 $ (0.25 ) $ (0.54 ) Diluted $ 1.90 $ 0.69 $ (0.25 ) $ (0.54 ) ____________________ (1) Includes (gain) loss on derivative contracts of $(34.2) million , $(23.5) million , $11.7 million and $21.9 million for the first, second, third and fourth quarters, respectively. (2) Includes terminated merger costs of $8.2 million for the fourth quarter. 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 ) ____________________ (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 10 for further discussion of impairment. (2) Includes loss on settlement of contract of $89.1 million and gain on extinguishment of debt 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

Summary of Significant Accoun30

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2017
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 North Park Basin regions of the United States. The Company’s North Park Basin properties were acquired during the fourth quarter of 2015.
Principles of Consolidation	Principles of Consolidation. The consolidated financial statements include the accounts of the Company and its wholly owned or majority owned subsidiaries. During the year ended December 31, 2015, 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 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 years ended December 31, 2017 , and December 31, 2016
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.
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
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 collectibility 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 8
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 7
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 7
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 13
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 Successor Company capitalized internal costs of $14.8 million and $4.0 million during the year ended December 31, 2017 and the Successor 2016 Period, respectively, and the Predecessor Company capitalized internal costs of $22.7 million and $45.1 million to the full cost pool during the Predecessor 2016 Period and the year ended December 31, 2015 , 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 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%
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 10
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 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 are the timing of settlement and changes in the legal, regulatory, environmental and political environments, which are subject to change. See Note 14 for further discussion of the Company’s asset retirement obligations. As part of fresh start accounting, the ARO liabilities were adjusted to their estimated fair value as described in Note 2 .
Revenue Recognition	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 $29.1 million and $7.4 million of transportation costs as a reduction from revenues in the year ended December 31, 2017 and the Successor 2016 Period, respectively, versus the presentation of $26.2 million and $45.3 million , respectively, of these costs as production expenses in the Predecessor 2016 Period and the year ended December 31, 2015, respectively. 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 more or less than 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 $1.6 million and $1.7 million at December 31, 2017 and 2016 , respectively. The Company includes the gas imbalance positions in other long-term obligations in the consolidated balance sheets. During the year ended December 31, 2015, 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 year ended December 31, 2015. 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 year ended December 31, 2015.
Natural Gas Balancing	<div style="font-family:Times New Roman;font-size:10pt;"><div style="line-height:120%;text-align:justify;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">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 more or less than 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 $1.6 million and $1.7 million at December 31, 2017 and 2016, respectively. The Company includes the gas imbalance positions in other long-term obligations in the consolidated balance sheets.</font></div></div>
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.Forfeitures for these awards are recognized as they occur.
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, during the Successor 2016 Period, the Company assumed the conversion of the Convertible Notes to common stock and determined if it was more dilutive than including the expense associated with the Convertible Notes in the computation of income available to common stockholders during the period the Convertible Notes were outstanding. 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 20
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. Environmental liabilities related to future costs are recorded on an undiscounted basis when assessments and/or remediation activities are probable and costs can be reasonably estimated. See Note 15
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 credit facility constitutes a default under its commodity derivative contracts with counterparties that are lenders under the credit facility. The Company does not require collateral or other security from counterparties to support commodity derivative instruments. The Company has master netting agreements with all of its commodity derivative counterparties, which allow the Company to net its commodity derivative assets and liabilities 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 credit facility can be offset against amounts owed, if any, to such counterparty under the Company’s credit facility. The Company operates a substantial portion of its oil and natural gas properties. As the operator of a property, the Company makes full payment for costs associated with the property and seeks reimbursement from the other working interest owners in the property for their share of those costs. The Company’s joint interest partners consist primarily of independent oil and natural gas producers. If the oil and natural gas exploration and production industry in general was adversely affected, the ability of the joint interest partners to reimburse the Company could be adversely affected. The purchasers of the Company’s oil, natural gas and NGL production consist primarily of independent marketers, major oil and natural gas companies and gas pipeline companies. 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 December 31, 2017 - Successor Targa Pipeline Mid-Continent West OK LLC $ 144,583 40.5 % Plains Marketing, L.P. $ 117,927 33.0 % 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 %
Recent Accounting Pronouncements	Recent Accounting Pronouncements. The Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“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 adopted the ASU on April 1, 2017. The guidance had no impact on the consolidated financial statements and related disclosures. The FASB Issued ASU 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business,” which provides a new framework for determining whether transactions should be accounted for as acquisitions (or disposals) of assets or as a business. The ASU is effective for the Company on January 1, 2018, and amendments should be applied prospectively on and after January 1, 2018. Early application is permitted for transactions for which the acquisition date occurs before the issuance date or effective date of the amendments, only when the transaction has not been reported in financial statements that have been issued or made available for issuance and for transactions in which a subsidiary is deconsolidated or a group of assets is derecognized that occur before the issuance date or effective date of the amendments, only when the transaction has not been reported in the financial statements that have been issued or made available for issuance. The Company applied this ASU for transactions effective after April 1, 2017 meeting the early application provisions above. The guidance had no impact to the Company’s consolidated financial statements and related disclosures upon adoption. The FASB issued ASU 2017-09, “Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting,” which provides guidance on determining which changes to the terms and conditions of share-based payment awards require an entity to apply modification accounting. The amendments in this ASU are effective for the Company on January 1, 2018, with early adoption permitted in any interim period. The ASU should be applied prospectively to an award modified on or after the adoption date. The Company early adopted this ASU on July 1, 2017. The guidance had no impact on the consolidated financial statements and related disclosures. The FASB issued ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” which outlines a single comprehensive model for entities to use in accounting for revenue arising 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 adopted Topic 606 on January 1, 2018, using the modified retrospective transition method. Subsequent to the issuance of ASU 2014-09, the FASB issued various clarifications and interpretive guidance to assist entities with implementation efforts, including guidance pertaining to the presentation of revenues on a gross basis (revenues presented separately from associated expenses) versus a net basis. Under this guidance, an entity generally shall record revenue on a gross basis if it controls a specified good or service before transferring it to a customer, whereas an entity shall record revenue on a net basis if its role is to arrange for another entity to provide the goods or services to a customer. Significant judgment may be required in some circumstances to determine whether gross or net presentation is appropriate. The Company has reviewed its contracts with customers and determined that this ASU will have no material impact on its balance sheet or related consolidated statement of earnings, stockholders’ equity or cash flows; however, the Company’s quarterly disclosures will expand in 2018 upon adoption of this ASU. The Company has implemented a process to gather and provide the quarterly disclosures required by the ASU. The FASB issued ASU 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other than Inventory” which removes the prohibition in Accounting Standards Codification (“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 adopted the ASU on January 1, 2018. There was no impact to the Company’s consolidated financial statements and related disclosures upon adoption. The FASB issued ASU 2017-05, “Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic: 610-20): Clarifying the Scope of Asset Derecognition Guidance and the Accounting for Partial Sales of Nonfinancial Assets,” which helps filers determine the guidance applicable for gain/loss recognition subsequent to the adoption of ASU 2014-09, Revenue from Contracts with Customers. The amendments also clarify that the derecognition of all businesses except those related to conveyances of oil and gas rights or contracts with customers should be accounted for in accordance with the derecognition and deconsolidation guidance in Topic 810, Consolidation. The Company adopted the ASU on January 1, 2018, using the modified retrospective transition method. Under this transition method the Company may elect to apply this guidance retrospectively either to all contracts at the date of initial application or only to contracts that are not completed contracts at the date of initial application. The Company elected to evaluate only contracts that are not completed contracts. As there were no not completed contracts at January 1, 2018, there was no impact to the Company’s consolidated financial statements and related disclosures upon adoption. Recent Accounting Pronouncements Not Yet Adopted. The FASB issued ASU 2016-02, “Leases (Topic 842),” which requires companies to recognize the assets and liabilities for the rights and obligations of all leases with a term greater than 12 months (long-term) on the balance sheet. Leases to explore for or use minerals, oil and natural gas are not impacted by this guidance. In January 2018, the FASB issued ASU 2018-01, “Leases (Topic 842), Land Easement Practical Expedient for Transition to Topic 842.” This ASU permits an entity to continue to apply its current accounting policy for land easements that existed before the effective date of Topic 842. Once an entity adopts Topic 842, it would apply that Topic prospectively to all new (or modified) land easements to determine whether the arrangement contains a lease. Topic 842 requires adoption by application of a modified retrospective transition approach and is effective for the Company on January 1, 2019. Early adoption is permitted.
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, 2017
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 stoc k 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 Building Note (36,610 ) Less: Asset retirement obligation (92,412 ) Less: Fair value of First Lien Exit Facility (414,954 ) Less: Fair value of 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 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 Building Note, $281.8 million of the Convertible Notes, and the $415.0 million drawn on the 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 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 - Common Stock 575,144 Additional paid in capital - premium on 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 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 Convertible Notes of $445.7 million and the principal value of the 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 7 . 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 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.
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 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, 2017
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 December 31, 2017 - Successor Targa Pipeline Mid-Continent West OK LLC $ 144,583 40.5 % Plains Marketing, L.P. $ 117,927 33.0 % 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 %

Supplemental Cash Flow Inform33

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2017
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 Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Supplemental Disclosure of Cash Flow Information Cash paid for reorganization items $ — $ — $ (55,606 ) $ — Cash paid for interest, net of amounts capitalized $ (2,438 ) $ (1,183 ) $ (104,609 ) $ (296,386 ) Cash (paid) received for income taxes $ 4,348 $ — $ (28 ) $ (88 ) 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 $ (28,999 ) $ 10,630 $ 25,045 $ 177,586 Equity issued for debt $ (268,779 ) $ (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 )

Recent Transactions (Tables)

Recent Transactions (Tables)	12 Months Ended
	Dec. 31, 2017
Extractive Industries [Abstract]
Schedule of Development Costs and Working Interest Structure	Development Costs and Working Interest (“WI”) Structure Counterparty SandRidge Development Costs 90% of Costs 10% of Costs Initial Working Interest 80% of WI 20% of WI Reversion If Counterparty Achieves 10% IRR 35% of WI 65% of WI Reversion If Counterparty Achieves 15% IRR 11% of WI 89% of WI Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Acquisitions of properties Proved $ 7,092 $ 5,142 $ 3,897 $ 35,376 Unproved 91,139 5,491 1,899 210,065 Exploration(1) 8,850 — 1,234 29,297 Development 187,264 27,429 149,924 571,562 Total cost incurred $ 294,345 $ 38,062 $ 156,954 $ 846,300 ____________________ (1) Includes 3-D seismic costs of $7.1 million for the year ended December 31, 2015 .

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017 - Successor Fair Value Measurements Netting(1) Assets/Liabilities at Fair Value Level 1 Level 2 Level 3 Assets Commodity derivative contracts $ — $ 5,582 $ — $ (4,272 ) $ 1,310 Investments $ 5,072 $ — $ — $ — $ 5,072 $ 5,072 $ 5,582 $ — $ (4,272 ) $ 6,382 Liabilities Commodity derivative contracts $ — $ 18,467 $ — $ (4,272 ) $ 14,195 $ — $ 18,467 $ — $ (4,272 ) $ 14,195 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 ____________________ (1)
Fair Value, Reconciliation of Level 3 Fair Value Measurements - Liabilities	The table below sets forth a reconciliation of the Predecessor Company’s Level 3 fair value measurements for debt holder conversion features (in thousands): Predecessor Period from January 1, 2016 through October 1, 2016 Beginning balance $ 29,355 Gain on derivative holder conversion feature (880 ) Conversions (21,194 ) Write off of derivative holder conversion feature to reorganization items (7,281 ) Ending level 3 debt holder conversion feature balance $ —
Estimated Fair Value and Carrying Value of the Company's Notes	The estimated fair values and carrying values of the Company’s long-term debt are as follows (in thousands): December 31, 2017 December 31, 2016 Fair Value Carrying Value Fair Value Carrying Value Convertible Notes $ — $ — $ 334,800 $ 268,780 Building Note $ 42,526 $ 37,502 $ 40,608 $ 36,528

Accounts Receivable (Tables)

Accounts Receivable (Tables)	12 Months Ended
	Dec. 31, 2017
Receivables [Abstract]
Summary of Accounts Receivable	A summary of accounts receivable is as follows (in thousands): December 31, 2017 2016 Oil, natural gas and NGL sales $ 34,570 $ 42,631 Joint interest billing 26,496 17,338 Oil and natural gas services 639 736 Other 10,846 14,272 Total accounts receivable 72,551 74,977 Less: allowance for doubtful accounts (1,274 ) (880 ) Total accounts receivable, net $ 71,277 $ 74,097
Balance and Activity in Allowance for Doubtful Accounts	The following table presents the balance and activity in the allowance for doubtful accounts for the year ended December 31, 2017 , the Successor 2016 Period, the Predecessor 2016 Period and year ended December 31, 2015 (in thousands): Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Beginning balance $ 880 $ — $ 4,847 $ 7,083 Additions charged to costs and expenses(1) 397 880 16,695 1,320 Deductions(2) (3 ) — (751 ) (3,556 ) Impact of fresh start accounting — — (20,791 ) — Ending balance $ 1,274 $ 880 $ — $ 4,847 ____________________ (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 the write-off of receivables and collections of amounts for which an allowance had previously been established. Deductions in 2016 are primarily due to the write-off of receivables in conjunction with a lawsuit settlement and deductions in 2015

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment consists of the following (in thousands): December 31, 2017 2016 Oil and natural gas properties Proved $ 1,056,806 $ 840,201 Unproved 100,884 74,937 Total oil and natural gas properties 1,157,690 915,138 Less accumulated depreciation, depletion and impairment (460,431 ) (353,030 ) Net oil and natural gas properties capitalized costs 697,259 562,108 Land 4,500 5,100 Electrical infrastructure 131,010 130,242 Non-oil and natural gas equipment 26,809 35,768 Buildings and structures 79,548 88,603 Total 241,867 259,713 Less accumulated depreciation and amortization (15,886 ) (3,889 ) Other property, plant and equipment, net 225,981 255,824 Total property, plant and equipment, net $ 923,240 $ 817,932
Capitalized Costs of Unproved Properties Excluded from Amortization	The following table summarizes the costs, by year incurred, related to unproved properties, which were excluded from oil and natural gas properties subject to amortization at December 31, 2017 (in thousands): Year Cost Incurred Total 2017 2016 2015 2014 and Prior Property acquisition $ 96,450 $ 42,827 $ 15,610 $ 19,481 $ 18,532 Exploration 4,434 1,904 678 1,453 399 Total costs incurred $ 100,884 $ 44,731 $ 16,288 $ 20,934 $ 18,931

Impairment (Tables)

Impairment (Tables)	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Schedule of Impairment by Asset Class	Impairment consists of the following (in thousands): Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Full cost pool ceiling limitation(1)(2) $ — $ 319,087 $ 657,392 $ 4,473,787 Drilling assets(3)(4) 4,019 — 3,511 37,646 Electrical infrastructure assets(5) — — 55,600 — Midstream assets(6) — — 1,691 7,148 Other(7) — — — 16,108 $ 4,019 $ 319,087 $ 718,194 $ 4,534,689 ____________________ (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 recorded in the year ended 2017 reflects the write-down of remaining drilling and oilfield services assets classified as held for sale to net realizable value. (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. (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 year ended December 31, 2015 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

Accounts Payable and Accrued 39

Accounts Payable and Accrued Expenses (Tables)	12 Months Ended
	Dec. 31, 2017
Payables and Accruals [Abstract]
Accounts Payable and Accrued Expenses	Accounts payable and accrued expenses consist of the following (in thousands): December 31, 2017 2016 Accounts payable and other accrued expenses $ 94,406 $ 65,408 Accrued interest 1,385 648 Production payable 18,059 16,011 Payroll and benefits 21,475 33,606 Drilling advances 3,830 844 Total accounts payable and accrued expenses $ 139,155 $ 116,517

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2017
Debt Disclosure [Abstract]
Long-Term Debt	Long-term debt consists of the following (in thousands): December 31, December 31, 2017 2016 Credit facility $ — $ — Convertible Notes — 268,780 Building Note 37,502 36,528 Total debt 37,502 305,308 Less: current maturities of long-term debt — — Long-term debt $ 37,502 $ 305,308

Derivatives (Tables)

Derivatives (Tables)	12 Months Ended
	Dec. 31, 2017
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 credit facility as of December 31, 2017 and the First Lien Exit Facility as of December 31, 2016 (in thousands): December 31, 2017 Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount Assets Derivative contracts - current $ 5,582 $ (4,272 ) $ 1,310 $ — $ 1,310 Derivative contracts - noncurrent — — — — — Total $ 5,582 $ (4,272 ) $ 1,310 $ — $ 1,310 Liabilities Derivative contracts - current $ 14,899 $ (4,272 ) $ 10,627 $ (10,627 ) $ — Derivative contracts - noncurrent 3,568 — 3,568 (3,568 ) — Total $ 18,467 $ (4,272 ) $ 14,195 $ (14,195 ) $ — December 31, 2016 Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount 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 ) $ —
Open Oil and Natural Gas Commodity Derivative Contracts	At December 31, 2017 , the Company’s open commodity derivative contracts consisted of the following: Oil Price Swaps Notional (MBbls) Weighted Average Fixed Price January 2018 - December 2018 3,464 $ 55.08 January 2019 - December 2019 1,460 $ 53.34 Natural Gas Price Swaps Notional (MMcf) Weighted Average Fixed Price January 2018 - December 2018 17,300 $ 3.16
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): December 31, December 31, Type of Contract Balance Sheet Classification 2017 2016 Derivative assets Oil price swaps Derivative contracts - current $ — $ — Natural gas price swaps Derivative contracts - current 5,582 — Oil price swaps Derivative contracts - noncurrent — — Natural gas price swaps Derivative contracts - noncurrent — — Derivative liabilities Oil price swaps Derivative contracts - current (14,899 ) (13,395 ) Natural gas price swaps Derivative contracts - current — (14,143 ) Oil price swaps Derivative contracts - noncurrent (3,568 ) (2,105 ) Natural gas price swaps Derivative contracts - noncurrent — (71 ) Total net derivative contracts $ (12,885 ) $ (29,714 )

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2017
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 Company’s asset retirement obligations (in thousands): Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Beginning balance $ 106,481 $ 92,413 $ 103,578 $ 54,402 Liability incurred upon acquiring and drilling wells 1,336 121 505 1,662 Revisions in estimated cash flows(1) (28,565 ) 12,397 — 44,060 Liability settled or disposed in current period(2) (11,308 ) (540 ) (36,979 ) (1,023 ) Accretion 9,600 2,090 4,365 4,477 Impact of fresh start accounting — — 20,944 — Ending balance 77,544 106,481 92,413 103,578 Less: current portion 41,017 66,154 65,678 8,399 Asset retirement obligations, net of current $ 36,527 $ 40,327 $ 26,735 $ 95,179 ____________________ (1) Revisions for the year ended December 31, 2017, the Successor 2016 Period and the year ended December 31, 2015 relate primarily to changes in estimated well lives and changes in oil and natural gas prices. (2) Liability settled or disposed for the Predecessor 2016 Period includes $34.1 million

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2017
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% and 7.0% convertible perpetual preferred stock are as follows (in thousands): Predecessor Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 8.5% Convertible perpetual preferred stock Dividends paid in cash $ — $ 11,262 Dividends satisfied in shares of common stock(1) $ — $ 11,262 Accrued dividends at period end $ — $ 8,447 Dividends in arrears $ 11,262 $ — 7.0% Convertible perpetual preferred stock Dividends paid in cash $ — $ — Dividends satisfied in shares of common stock(2) $ — $ 10,500 Accrued dividends at period end $ — $ 13,125 Dividends in arrears $ 21,000 $ 10,500 ____________________ (1) For the year ended December 31, 2015 , the Company paid a semi-annual dividend by issuing approximately 18.6 million shares of common stock. For purposes of the dividend payment, the value of each share issued was calculated as 95% of the average volume-weighted share price for the 15 trading day period ending July 29, 2015. Based upon the common stock’s closing price on August 17, 2015, the common stock issued had a market value of approximately $9.5 million , ( $3.58 per outstanding share at the time the dividend was paid) that resulted in a difference between the fixed rate semi-annual dividend and the value of shares issued of approximately $1.8 million , which was recorded as a reduction to preferred stock dividends in the accompanying 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 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. Successor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Number of shares withheld for taxes 349 5 Value of shares withheld for taxes $ 6,730 $ 110

Share Based Compensation (Table

Share Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2017
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, 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 — $ — 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 Granted 671 $ 19.97 Vested (827 ) $ 23.23 Forfeited / Canceled (146 ) $ 23.52 Unvested restricted shares outstanding at December 31, 2017 1,105 $ 22.62

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2017
Income Tax Disclosure [Abstract]
(Benefit) Provision for Income Taxes	The Company’s income tax (benefit) provision consisted of the following components (in thousands): Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Current Federal $ (8,719 ) $ — $ — $ — State (30 ) 9 11 123 (8,749 ) 9 11 123 Deferred Federal — — — — State — — — — — — — — Total (benefit) provision (8,749 ) 9 11 123 Less: income tax provision attributable to noncontrolling interest — — — 90 Total (benefit) provision attributable to SandRidge Energy, Inc. $ (8,749 ) $ 9 $ 11 $ 33
Reconciliation of Provision (Benefit) for Income Taxes at Statutory Federal Tax Rate	A reconciliation of the (benefit) provision for income taxes at the statutory federal tax rate to the Company’s actual income tax (benefit) provision is as follows (in thousands): Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Computed at federal statutory rate $ 13,409 $ (116,891 ) $ 504,283 $ (1,512,325 ) State taxes, net of federal benefit (284 ) (3,696 ) 10,512 (19,988 ) Non-deductible expenses 1,711 144 462 816 Non-deductible debt costs — — 22,694 10,228 Stock-based compensation 1,109 306 5,884 6,700 Net effects of consolidating the non-controlling interests’ tax provisions — — — 218,196 Discharge of debt and other reorganization related items 1,018 — 359,278 — Return to provision adjustments (1) 341,681 — — — Impact of legislative changes 243,801 — — — Release of valuation allowance (8,719 ) — — — Change in valuation allowance (602,452 ) 120,144 (903,102 ) 1,296,405 Other (23 ) 2 — 1 Total (benefit) provision attributable to SandRidge Energy, Inc. $ (8,749 ) $ 9 $ 11 $ 33 ____________________ (1) Primarily related to the Company’s decision to file its 2016 income tax returns using an alternate method than previously estimated with respect to its Chapter 11 related transactions. See additional discussion with respect to Internal Revenue Code (“IRC”) Section 382 below.
Deferred Tax Assets and Liabilities	Significant components of the Company’s deferred tax assets and liabilities are as follows (in thousands): December 31, 2017 December 31, 2016 Deferred tax liabilities Investments(1) $ 171,517 $ 275,128 Total deferred tax liabilities 171,517 275,128 Deferred tax assets Property, plant and equipment 391,273 751,683 Derivative contracts 3,131 11,274 Allowance for doubtful accounts 986 1,487 Net operating loss carryforwards 217,259 527,079 Compensation and benefits 5,700 14,494 Tax Credits and other carryforwards 33,001 43,770 Asset retirement obligations 18,843 40,399 Other 2,273 4,663 Total deferred tax assets 672,466 1,394,849 Valuation allowance (500,949 ) (1,119,721 ) Net deferred tax liability $ — $ — ____________________ (1)
Unrecognized Tax Benefits	A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows (in thousands): Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Unrecognized tax benefit at January 1 $ 84 $ 81 $ 81 Changes to unrecognized tax benefits related to a prior period 2 3 — Lapse of statute of limitations (38 ) — — Unrecognized tax benefit at December 31 $ 48 $ 84 $ 81

Earnings (Loss) per Share (Tabl

Earnings (Loss) per Share (Tables)	12 Months Ended
	Dec. 31, 2017
Earnings Per Share [Abstract]
Calculation of Weighted Average Common Shares Outstanding used in Computation of Diluted Earnings Per Share	The following table summarizes the calculation of weighted average common shares outstanding used in the computation of diluted earnings (loss) per share: Net Income (Loss) Weighted Average Shares Earnings (Loss) Per Share (In thousands, except per share amounts) Year Ended December 31, 2017 (Successor) Basic earnings per share $ 47,062 32,442 $ 1.45 Effect of dilutive securities Restricted stock awards — 221 Performance share units(1) — — Warrants(1) — — Diluted earnings per share $ 47,062 32,663 $ 1.44 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(2) — — Warrants(2) — — Convertible Notes(3) — — 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(4) — — 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(4) — — Convertible preferred stock (5) — — Convertible senior unsecured notes(6) — — Diluted loss per share $ (3,735,495 ) 521,936 $ (7.16 ) ____________________ (1) No incremental shares of potentially dilutive performance share units or warrants were included for the year ended December 31, 2017 , as their effect was antidilutive. See Note 17 for discussion of the Company’s share and incentive-based compensation awards. (2) No incremental shares of potentially dilutive restricted stock awards or warrants were included for the Successor 2016 Period as their effect was antidilutive. (3) Potential common shares related to the 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. (4) 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. (5) Potential common shares related to the Predecessor Company’s then-outstanding 8.5% and 7.0% convertible perpetual preferred stock covering 71.2 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. (6) 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 O47

Supplemental Information on Oil and Natural Gas Producing Activities (Tables)	12 Months Ended
	Dec. 31, 2017
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, December 31, 2017 2016 2015 Oil and natural gas properties Proved $ 1,056,806 $ 840,201 $ 12,529,681 Unproved 100,884 74,937 363,149 Total oil and natural gas properties 1,157,690 915,138 12,892,830 Less accumulated depreciation, depletion and impairment (460,431 ) (353,030 ) (11,149,888 ) Net oil and natural gas properties capitalized costs $ 697,259 $ 562,108 $ 1,742,942
Cost Incurred in Oil and Natural Gas Property Acquisition, Exploration, and Development	Development Costs and Working Interest (“WI”) Structure Counterparty SandRidge Development Costs 90% of Costs 10% of Costs Initial Working Interest 80% of WI 20% of WI Reversion If Counterparty Achieves 10% IRR 35% of WI 65% of WI Reversion If Counterparty Achieves 15% IRR 11% of WI 89% of WI Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Acquisitions of properties Proved $ 7,092 $ 5,142 $ 3,897 $ 35,376 Unproved 91,139 5,491 1,899 210,065 Exploration(1) 8,850 — 1,234 29,297 Development 187,264 27,429 149,924 571,562 Total cost incurred $ 294,345 $ 38,062 $ 156,954 $ 846,300 ____________________ (1) Includes 3-D seismic costs of $7.1 million for the year ended December 31, 2015 .
Results of Operations for Oil, Natural Gas and NGL Producing Activities	The following table presents the Company’s results of operations from oil and natural gas producing activities (in thousands), which exclude any interest costs or indirect general and administrative costs and, therefore, are not necessarily indicative of the contribution to net earnings of the Company’s operations. Successor Predecessor Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Revenues $ 356,210 $ 98,307 $ 279,971 $ 707,434 Expenses Production costs 116,372 27,640 135,715 324,141 Depreciation and depletion 118,035 36,061 90,978 324,390 Impairment — 319,087 657,392 4,473,787 Total expenses 234,407 382,788 884,085 5,122,318 Income (loss) before income taxes 121,803 (284,481 ) (604,114 ) (4,414,884 ) Income tax expense (benefit)(1) 47,722 (112,427 ) (229,986 ) (1,680,746 ) Results of operations for oil and natural gas producing activities (excluding corporate overhead and interest costs) $ 74,081 $ (172,054 ) $ (374,128 ) $ (2,734,138 ) ____________________ (1) Income tax expense (benefit) is hypothetical and is calculated by applying the Company’s statutory tax rate to income (loss) before income taxes attributable to our oil and natural gas producing activities, after giving effect to permanent differences and tax credits.
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 Total (MBbls) (MBbls) (MMcf)(1) MBoe Proved developed and undeveloped reserves As of December 31, 2014(2) - Predecessor 126,031 91,786 1,788,233 515,856 Revisions of previous estimates (70,708 ) (37,384 ) (759,106 ) (234,610 ) Acquisitions of new reserves 22,447 2,460 15,952 27,566 Extensions and discoveries 9,741 9,257 160,865 45,809 Production (9,600 ) (5,044 ) (92,104 ) (29,995 ) As of December 31, 2015(2) - Predecessor 77,911 61,075 1,113,840 324,626 Adoption of ASU 2015-02 (6,971 ) (3,695 ) (50,508 ) (19,084 ) Revisions of previous estimates (39,973 ) (21,475 ) (415,568 ) (130,709 ) Extensions and discoveries 987 472 7,955 2,785 Sales of reserves in place (387 ) — (145,267 ) (24,598 ) Production (4,315 ) (3,358 ) (44,124 ) (15,027 ) As of October 1, 2016 - Predecessor 27,252 33,019 466,328 137,992 Revisions of previous estimates 23,978 1,139 915 25,270 Extensions and discoveries 2,868 448 10,309 5,034 Production (1,214 ) (999 ) (12,770 ) (4,341 ) As of December 31, 2016 - Successor 52,884 33,607 464,782 163,955 Revisions of previous estimates 804 2,628 44,679 10,879 Acquisitions of new reserves 18 70 683 202 Extensions and discoveries 12,446 1,914 30,080 19,373 Sales of reserves in place (204 ) (529 ) (7,055 ) (1,909 ) Production (4,157 ) (3,376 ) (44,237 ) (14,906 ) As of December 31, 2017 - Successor 61,791 34,314 488,932 177,594 Proved developed reserves As of December 31, 2014 - Predecessor 79,022 56,823 1,203,447 336,420 As of December 31, 2015 - Predecessor 48,639 51,089 964,617 260,498 As of October 1, 2016 - Predecessor 24,541 30,238 428,050 126,121 As of December 31, 2016 - Successor 25,911 29,290 393,028 120,706 As of December 31, 2017 - Successor 25,845 29,922 407,988 123,765 Proved undeveloped reserves As of December 31, 2014 - Predecessor 47,009 34,963 584,786 179,436 As of December 31, 2015 - Predecessor 29,272 9,986 149,223 64,129 As of October 1, 2016 - Predecessor 2,711 2,781 38,278 11,872 As of December 31, 2016 - Successor 26,973 4,317 71,754 43,249 As of December 31, 2017 - Successor 35,946 4,392 80,944 53,829 ____________________ (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, December 31, 2017 2016 2015 Oil (per barrel) $ 48.47 $ 38.59 $ 45.29 NGL (per barrel) $ 20.28 $ 10.99 $ 12.68 Natural gas (per Mcf) $ 1.90 $ 1.56 $ 1.87
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, December 31, 2017 2016 2015 Future cash inflows from production $ 4,621,615 $ 3,136,762 $ 6,387,944 Future production costs (1,837,852 ) (1,454,798 ) (2,731,542 ) Future development costs(1) (966,203 ) (665,516 ) (838,945 ) Future income tax expenses (107 ) (142 ) (901 ) Undiscounted future net cash flows 1,817,453 1,016,306 2,816,556 10% annual discount (1,068,159 ) (577,942 ) (1,501,994 ) Standardized measure of discounted future net cash flows(2) $ 749,294 $ 438,364 $ 1,314,562 ____________________ (1) Includes abandonment costs. (2) Includes approximately $224.6 million attributable to noncontrolling interests at December 31, 2015
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 Year Ended December 31, 2017 Period from October 2, 2016 through December 31, 2016 Period from January 1, 2016 through October 1, 2016 Year Ended December 31, 2015 Beginning present value $ 438,364 $ 392,604 $ 1,314,562 $ 4,087,752 Changes during the year Adoption of ASU 2015-02 — — (224,965 ) — Revenues less production (239,838 ) (70,668 ) (144,256 ) (383,293 ) Net changes in prices, production and other costs 347,458 35,684 (394,173 ) (3,813,465 ) Development costs incurred 35,517 7,941 69,080 217,596 Net changes in future development costs (64,484 ) (291,232 ) 436,041 273,437 Extensions and discoveries 112,556 14,986 12,449 230,055 Revisions of previous quantity estimates 26,697 308,374 (728,254 ) (1,354,778 ) Accretion of discount 37,226 9,375 91,337 512,483 Net change in income taxes 23 — 402 1,426,333 Purchases of reserves in-place 454 — — 18,429 Sales of reserves in-place (2,977 ) — (13,314 ) — Timing differences and other(1) 58,298 31,300 (26,305 ) 100,013 Net change for the year 310,930 45,760 (921,958 ) (2,773,190 ) Ending present value(2) $ 749,294 $ 438,364 $ 392,604 $ 1,314,562 ____________________ (1) The change in timing differences and other are related to revisions in the Company’s estimated time of production and development. (2) Includes approximately $224.6 million

Quarterly Financial Results (48

Quarterly Financial Results (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Results (Unaudited)	The Company’s operating results for each quarter of 2017 and 2016 are summarized below (in thousands, except per share data). Successor First Quarter Second Quarter Third Quarter Fourth Quarter 2017 Total revenues $ 98,350 $ 84,851 $ 80,892 $ 93,206 Income (loss) from operations(1)(2) $ 50,780 $ 23,348 $ (16,267 ) $ (18,230 ) Net income (loss)(1)(2) $ 50,808 $ 23,499 $ (8,485 ) $ (18,760 ) Income available (loss applicable) to SandRidge Energy, Inc. common stockholders(1)(2) $ 50,808 $ 23,499 $ (8,485 ) $ (18,760 ) Income available (loss applicable) per share to SandRidge Energy, Inc. common stockholders Basic $ 1.90 $ 0.69 $ (0.25 ) $ (0.54 ) Diluted $ 1.90 $ 0.69 $ (0.25 ) $ (0.54 ) ____________________ (1) Includes (gain) loss on derivative contracts of $(34.2) million , $(23.5) million , $11.7 million and $21.9 million for the first, second, third and fourth quarters, respectively. (2) Includes terminated merger costs of $8.2 million for the fourth quarter. 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 ) ____________________ (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 10 for further discussion of impairment. (2) Includes loss on settlement of contract of $89.1 million and gain on extinguishment of debt 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

Chapter 11 Bankruptcy - Narrati

Chapter 11 Bankruptcy - Narrative (Details) - USD ($) $ / shares in Units, shares in Millions	Feb. 10, 2017	Oct. 01, 2016	Feb. 28, 2017	Feb. 09, 2017	Dec. 31, 2016	Feb. 09, 2017	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015
Predecessor | Convertible Debt
Restructuring Cost and Reserve [Line Items]
Notes exchanged/converted							$ 232,100,000		$ 255,300,000
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%
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%
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%
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%
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%
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%
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%
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 | 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%
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		4.9					4.9
Shares issued		4.5
Exercise price of warrants (in usd per share)		$ 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		2.1					2.1
Shares issued		1.9
Exercise price of warrants (in usd per share)		$ 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
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 | Building Note | Secured Notes
Restructuring Cost and Reserve [Line Items]
Face amount of debt instrument		35,000,000					35,000,000
Fair value of debt		36,600,000					$ 36,600,000
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		18.9					18.9
Predecessor | Plan of Reorganization | New Common Stock | Holders of Senior Secured Notes
Restructuring Cost and Reserve [Line Items]
Shares issued		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		5.7					5.7
Shares issued		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%
Successor
Restructuring Cost and Reserve [Line Items]
Face value of long-term debt					$ 305,308,000			$ 37,502,000
Successor | Series A Warrants
Restructuring Cost and Reserve [Line Items]
Number of shares to be issued		4.9					4.9
Shares issued		4.5						0.1
Exercise price of warrants (in usd per share)		$ 41.34					$ 41.34
Successor | Series B Warrants
Restructuring Cost and Reserve [Line Items]
Number of shares to be issued		2.1					2.1
Shares issued		1.9
Exercise price of warrants (in usd per share)		$ 42.03					$ 42.03
Successor | Amended New Credit Facility | Revolving Credit Facility
Restructuring Cost and Reserve [Line Items]
Line of credit facility, current borrowing capacity	$ 425,000,000
Maximum borrowing capacity	600,000,000
Face value of long-term debt								$ 0
Successor | New First Lien Exit Facility | Revolving Credit Facility
Restructuring Cost and Reserve [Line Items]
Maximum borrowing capacity		$ 425,000,000					$ 425,000,000
Face value of long-term debt					$ 0			0
Successor | Convertible Notes | Convertible Debt
Restructuring Cost and Reserve [Line Items]
Notes exchanged/converted	$ 263,700,000
Face amount of debt instrument		281,800,000					281,800,000
Fair value of debt		$ 445,700,000					$ 445,700,000
Annual interest rate		0.00%					0.00%
Common stock issued for debt (in shares)	14.1	15	14.1	0.3	0.7	1
Face value of long-term debt					$ 268,780,000			0
Successor | Building Note | Secured Notes
Restructuring Cost and Reserve [Line Items]
Face amount of debt instrument		$ 35,000,000					$ 35,000,000
Fair value of debt		36,600,000					$ 36,600,000
Proceeds from issuance of debt		$ 26,800,000
Face value of long-term debt					$ 36,528,000			$ 37,502,000
Successor | New Common Stock
Restructuring Cost and Reserve [Line Items]
Shares issued								0.1

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, 2017	Dec. 31, 2016	Oct. 01, 2016
Reconciliation of Enterprise Value to Fair Value
Enterprise value			$ 1,089,808
Cash and cash equivalents	$ 99,143	$ 121,231	563,372
Less: Fair value of Building Note			(36,610)
Less: Asset retirement obligation			(92,412)
Less: Fair value of First Lien Exit Facility			(414,954)
Less: Fair value of 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	35,650	19,635	19,371
Per share value (in dollars per share)			$ 29.31

Fresh Start Accounting - Reco52

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	$ 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 | Building Note | Secured Debt
Fresh-Start Adjustment [Line Items]
Increase in long-term debt	(35,000)
Reorganization Adjustments | 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
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
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 - Reor57

Fresh Start Accounting - Reorganization Adjustments to Equity (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2016
Reorganization Adjustments
Debtor Reorganization Adjustments, Equity [Abstract]
Par value of 18.9 million shares of 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
Reorganization Adjustments | 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
Reorganization Adjustments | New Common Stock
Debtor Reorganization Adjustments, Equity [Abstract]
Additional paid-in capital	$ 575,144
Reorganization Adjustments | Convertible Notes
Debtor Reorganization Adjustments, Equity [Abstract]
Additional paid-in capital	$ 163,879
Reorganization Adjustments | Series A Warrants | Warrants
Fair Value Assumptions and Methodology for Assets and Liabilities [Abstract]
Exercise price per share	$ 41.34
Reorganization Adjustments | Series B Warrants | Warrants
Fair Value Assumptions and Methodology for Assets and Liabilities [Abstract]
Exercise price per share	$ 42.03
Reorganization Adjustments | Convertible Debt | 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
Successor
Debtor Reorganization Adjustments, Equity [Abstract]
Common stock, issued (in shares)		35,650	21,042
Per share value (in dollars per share)	$ 29.31
Successor | Senior Secured and Unsecured Notes Holders
Debtor Reorganization Adjustments, Equity [Abstract]
Common stock, issued (in shares)	18,900
Per share value (in dollars per share)	$ 29.31
Successor | Convertible Debt | Convertible Notes
Fair Value Assumptions and Methodology for Assets and Liabilities [Abstract]
Fair value of debt	$ 445,700
Face amount of debt instrument	$ 281,800

Fresh Start Accounting - Fresh

Fresh Start Accounting - Fresh Start Adjustments (Details) - USD ($) $ in Thousands	Oct. 02, 2016	Oct. 01, 2016
Successor
Fresh-Start Adjustment [Line Items]
Accumulated deficit	$ 0	$ 0

Fresh Start Accounting - Reor59

Fresh Start Accounting - Reorganization Items (Details) - Predecessor - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Oct. 01, 2016	Dec. 31, 2015
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 Convertible Notes issued	(281,780)
Gain on reorganization items, net	$ 2,430,599	$ 0

Summary of Significant Accoun60

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, 2017	Dec. 31, 2015
Successor
Significant Accounting Policies [Line Items]
Allowance for doubtful accounts		$ 0
Capitalized costs	$ 38,062,000		$ 294,345,000
Maximum reserves sold from cost center not expected to result in significant alteration (less than)			25.00%
Natural gas balancing liability	1,700,000		$ 1,600,000
Successor | Internal Costs
Significant Accounting Policies [Line Items]
Capitalized costs	4,000,000		$ 14,800,000
Successor | Buildings and structures | Minimum
Significant Accounting Policies [Line Items]
Property, plant and equipment, useful life			10 years
Successor | Buildings and structures | 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 | Oil And Gas Unproved Properties
Significant Accounting Policies [Line Items]
Interest capitalized during period	0		$ 0
Successor | Oil, natural gas and NGL revenues
Significant Accounting Policies [Line Items]
Transportation costs	$ 7,400,000		$ 29,100,000
Predecessor
Significant Accounting Policies [Line Items]
Capitalized costs		156,954,000		$ 846,300,000
Predecessor | Internal Costs
Significant Accounting Policies [Line Items]
Capitalized costs		22,700,000		45,100,000
Predecessor | Oil And Gas Unproved Properties
Significant Accounting Policies [Line Items]
Interest capitalized during period		$ 2,200,000		10,800,000
Predecessor | Midstream And Corporate Assets
Significant Accounting Policies [Line Items]
Interest capitalized during period				$ 3,300,000
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%
Predecessor | Convertible Debt | 8.125% Convertible Senior Notes due 2022
Significant Accounting Policies [Line Items]
Long-term debt, fixed interest rate		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%
Predecessor | Production expenses
Significant Accounting Policies [Line Items]
Transportation costs		$ 26,200,000		$ 45,300,000

Summary of Significant Accoun61

Summary of Significant Accounting Policies - Concentration Risk (Details) - USD ($) $ in Thousands	Oct. 01, 2016	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015
Successor
Concentration Risk [Line Items]
Sales		$ 93,206	$ 80,892	$ 84,851	$ 98,350	$ 98,456					$ 357,299
Successor | Plains Marketing, L.P.
Concentration Risk [Line Items]
Sales						$ 32,022					$ 117,927
Percentage of revenue						32.50%					33.00%
Successor | Targa Pipeline Mid-Continent West OK LLC
Concentration Risk [Line Items]
Sales						$ 35,845					$ 144,583
Percentage of revenue						36.40%					40.50%
Predecessor
Concentration Risk [Line Items]
Sales	$ 0						$ 104,056	$ 99,421	$ 90,332	$ 293,809		$ 768,709
Predecessor | Plains Marketing, L.P.
Concentration Risk [Line Items]
Sales										$ 110,370		$ 318,018
Percentage of revenue										37.60%		41.40%
Predecessor | Targa Pipeline Mid-Continent West OK LLC
Concentration Risk [Line Items]
Sales										$ 108,238		$ 231,649
Percentage of revenue										36.80%		30.10%

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, 2017	Dec. 31, 2015
Successor
Supplemental Disclosure of Cash Flow Information
Cash paid for reorganization items	$ 0		$ 0
Cash paid for interest, net of amounts capitalized	(1,183)		(2,438)
Cash (paid) received for income taxes	0		4,348
Supplemental Disclosure of Noncash Investing and Financing Activities
Cumulative effect of adoption of ASU 2015-02	0		0
Property, plant and equipment transferred in settlement of contract	0		0
Change in accrued capital expenditures	10,630		(28,999)
Equity issued for debt	(13,001)		(268,779)
Preferred stock dividends paid in common stock	0		0
Long-term debt issued, including derivative and net of discount, for asset acquisition and termination of gathering agreement	$ 0		$ 0
Predecessor
Supplemental Disclosure of Cash Flow Information
Cash paid for reorganization items		$ (55,606)		$ 0
Cash paid for interest, net of amounts capitalized		(104,609)		(296,386)
Cash (paid) received for income taxes		(28)		(88)
Supplemental Disclosure of Noncash Investing and Financing Activities
Cumulative effect of adoption of ASU 2015-02		(247,566)		0
Property, plant and equipment transferred in settlement of contract		215,635		0
Change in accrued capital expenditures		25,045		177,586
Equity issued for debt		(4,409)		(63,299)
Preferred stock dividends paid in common stock		0		(16,188)
Long-term debt issued, including derivative and net of discount, for asset acquisition and termination of gathering agreement		$ 0		$ (50,310)

Recent Transactions (Details)

Recent Transactions (Details) - Successor - Drilling Participation Agreement - NW Stack $ in Millions	3 Months Ended
	Sep. 30, 2017USD ($)
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Percent of development costs to be funded	10.00%
Initial working interest per well	20.00%
Working interest per well if achievement of 10% IRR	65.00%
Working interest per well if achievement of 15% IRR	89.00%
Private Investment Fund
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Drilling participation agreement commitment	$ 200
Percent of development costs to be funded	90.00%
Drilling costs to be funded	$ 100
Initial working interest per well	80.00%
Optional additional funding	$ 100
Working interest per well if achievement of 10% IRR	35.00%
Working interest per well if achievement of 15% IRR	11.00%

Acquisitions and Divestitures -

Acquisitions and Divestitures - Acquisitions (Details) $ in Thousands	Feb. 10, 2017USD ($)awell	Dec. 31, 2015USD ($)awell	Oct. 31, 2015USD ($)mi	Dec. 31, 2016USD ($)	Mar. 31, 2016USD ($)	Oct. 01, 2016USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2015USD ($)awell
Successor
Business Acquisition [Line Items]
Number of acres acquired | a	13,000
Cash paid for acres	$ 47,800
Number of wells acquired | well	4
Payments to acquire oil and gas property and equipment				$ 0			$ 48,312
Loss on termination of the gathering contract				$ 0			$ 0
Predecessor
Business Acquisition [Line Items]
Payments to acquire oil and gas property and equipment						$ 1,328		$ 216,943
Loss on termination of the gathering contract					$ 89,100	$ 90,184		$ 50,976
Predecessor | 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
Predecessor | Rockies Properties | North Park Basin, Jackson County, Colorado
Business Acquisition [Line Items]
Number of wells acquired | well		16						16
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
Predecessor | Oil and Gas Properties | Pinon Gathering Company LLC
Business Acquisition [Line Items]
Fair value of assets acquired			$ 47,300
Predecessor | Senior Notes | 8.75% Senior Notes due 2020
Business Acquisition [Line Items]
Long-term debt, fixed interest rate						8.75%

Acquisitions and Divestitures65

Acquisitions and Divestitures - Divestitures (Details) - USD ($) $ in Thousands	Oct. 01, 2016	Jan. 21, 2016	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015
Successor
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Payment of certain contract cures and other							$ 0					$ 0
Loss on termination of the gathering contract							0					0
Revisions in estimated cash flows							12,397					(28,565)
Revenues			$ 93,206	$ 80,892	$ 84,851	$ 98,350	98,456					357,299
Expenses							$ 434,801					317,668
Successor | Oil and Gas Properties | Disposal Group, 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												$ 17,100
Predecessor
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Payment of certain contract cures and other											$ 11,000		$ 24,889
Loss on termination of the gathering contract										$ 89,100	90,184		50,976
Revisions in estimated cash flows											0		44,060
Revenues	$ 0							$ 104,056	$ 99,421	$ 90,332	293,809		768,709
Expenses											$ 1,200,012		$ 5,411,387
Predecessor | 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
Predecessor | 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)
Predecessor | 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
Loss on termination of the gathering contract		$ 89,100

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - USD ($) $ in Thousands	9 Months Ended
	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Predecessor | 7.5% Convertible Senior Notes due 2023
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate				7.50%
Predecessor | Senior Notes | 8.75% Senior Notes due 2020
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate	8.75%
Predecessor | Convertible Debt | 7.5% Convertible Senior Notes due 2023
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Long-term debt, fixed interest rate	7.50%
Predecessor | 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
Long-term Debt Holder Conversion Feature | Predecessor
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Write off of derivative holder conversion feature to reorganization items	(7,281)
Long-term Debt Holder Conversion Feature | Predecessor | Level 3
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Write off of derivative holder conversion feature to reorganization items	$ (7,300)
Recurring Measurement Basis | Successor
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Investments		$ 5,072	$ 7,541
Recurring Measurement Basis | Successor | Level 1
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Investments		5,072	7,541
Recurring Measurement Basis | Successor | Level 2
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Investments		0	0
Recurring Measurement Basis | Successor | Level 3
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Investments		0	0
Recurring Measurement Basis | Other Current Assets | Successor | Level 1
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Investments		$ 5,100	2,800
Recurring Measurement Basis | Other Assets | Successor | Level 1
Fair Value Assets And Liabilities Measured On Recurring Basis [Line Items]
Investments			$ 4,800

Fair Value Measurements - Signi

Fair Value Measurements - Significant Unobservable Inputs - Long Term Debt Conversion Feature (Details) - Predecessor - 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) - Successor - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative assets	$ 5,582
Derivative Liabilities	18,467	$ 29,714
Recurring Measurement Basis
Fair Value Assets And Liabilities Measured On Recurring Basis
Investments	5,072	7,541
Assets	6,382	7,541
Derivative Assets, Netting	(4,272)
Derivative Liabilities, Netting	(4,272)	0
Derivative Liabilities at Fair Value	14,195	29,714
Recurring Measurement Basis | Commodity derivative contracts
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative Assets, Netting	(4,272)
Derivative Assets at Fair Value	1,310
Derivative Liabilities, Netting	(4,272)	0
Derivative Liabilities at Fair Value	14,195	29,714
Recurring Measurement Basis | Level 1
Fair Value Assets And Liabilities Measured On Recurring Basis
Investments	5,072	7,541
Assets	5,072	7,541
Derivative Liabilities	0	0
Recurring Measurement Basis | Level 1 | Commodity derivative contracts
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative assets	0
Derivative Liabilities	0	0
Recurring Measurement Basis | Level 2
Fair Value Assets And Liabilities Measured On Recurring Basis
Investments	0	0
Assets	5,582	0
Derivative Liabilities	18,467	29,714
Recurring Measurement Basis | Level 2 | Commodity derivative contracts
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative assets	5,582
Derivative Liabilities	18,467	29,714
Recurring Measurement Basis | Level 3
Fair Value Assets And Liabilities Measured On Recurring Basis
Investments	0	0
Assets	0	0
Derivative Liabilities	0	0
Recurring Measurement Basis | Level 3 | Commodity derivative contracts
Fair Value Assets And Liabilities Measured On Recurring Basis
Derivative assets	0
Derivative Liabilities	$ 0	$ 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 $ in Thousands	9 Months Ended
	Oct. 01, 2016USD ($)
Level 3 Fair Value Measurements - Long-Term Debt Holder Conversion Feature
Beginning balance	$ 29,355
Gain on derivative holder conversion feature	(880)
Conversions	(21,194)
Write off of derivative holder conversion feature to reorganization items	(7,281)
Ending level 3 debt holder conversion feature balance	$ 0

Fair Value Measurements - Estim

Fair Value Measurements - Estimated Fair Value and Carrying Value of Long-term Debt (Details) - Successor - USD ($)	Dec. 31, 2017	Dec. 31, 2016	Oct. 01, 2016
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Value	$ 37,502,000	$ 305,308,000
Convertible Debt | Convertible Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Face amount of debt instrument			$ 281,800,000
Fair Value			445,700,000
Carrying Value	0	268,780,000
Secured Debt | Building Note
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Face amount of debt instrument			35,000,000
Fair Value			$ 36,600,000
Carrying Value	37,502,000	36,528,000
Level 2 | Convertible Debt | Convertible Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value	0	334,800,000
Level 2 | Secured Debt | Building Note
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value	$ 42,526,000	$ 40,608,000

Accounts Receivable - Summary o

Accounts Receivable - Summary of Accounts Receivable (Details) - Successor - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Oct. 01, 2016
Accounts, Notes, Loans and Financing Receivable [Line Items]
Oil, natural gas and NGL sales	$ 34,570	$ 42,631
Joint interest billing	26,496	17,338
Oil and natural gas services	639	736
Other	10,846	14,272
Total accounts receivable	72,551	74,977
Less: allowance for doubtful accounts	(1,274)	(880)	$ 0
Total accounts receivable, net	$ 71,277	$ 74,097

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, 2017	Dec. 31, 2015
Successor
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	$ 0		$ 880
Additions charged to costs and expenses	880		397
Deductions	0		(3)
Impact of fresh start accounting	0		0
Ending balance	880	$ 0	$ 1,274
Predecessor
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	$ 0	4,847		$ 7,083
Additions charged to costs and expenses		16,695		1,320
Deductions		(751)		(3,556)
Impact of fresh start accounting		(20,791)		0
Ending balance		$ 0		$ 4,847

Property, Plant and Equipment73

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Successor
Oil and natural gas properties, using full cost method of accounting
Proved	$ 1,056,806	$ 840,201
Unproved	100,884	74,937
Total oil and natural gas properties	1,157,690	915,138
Less: accumulated depreciation, depletion and impairment	(460,431)	(353,030)
Net oil and natural gas properties capitalized costs	697,259	562,108
Property, Plant and Equipment, Net
Total	241,867	259,713
Less accumulated depreciation and amortization	(15,886)	(3,889)
Other property, plant and equipment, net	225,981	255,824
Total property, plant and equipment, net	923,240	817,932
Successor | Land
Property, Plant and Equipment, Net
Total	4,500	5,100
Successor | Electrical infrastructure
Property, Plant and Equipment, Net
Total	131,010	130,242
Successor | Non-oil and natural gas equipment
Property, Plant and Equipment, Net
Total	26,809	35,768
Successor | Buildings and structures
Property, Plant and Equipment, Net
Total	$ 79,548	$ 88,603
Predecessor
Oil and natural gas properties, using full cost method of accounting
Proved			$ 12,529,681
Unproved			363,149
Total oil and natural gas properties			12,892,830
Less: accumulated depreciation, depletion and impairment			(11,149,888)
Net oil and natural gas properties capitalized costs			$ 1,742,942

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, 2017USD ($)$ / Boe	Dec. 31, 2015USD ($)$ / Boe
Predecessor
Property, Plant and Equipment [Line Items]
Full cost ceiling impairments		$ 657,392,000		$ 4,473,787,000
Average depreciation and depletion rate (usd per Boe) | $ / Boe		6.05		10.81
Successor
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 259,713,000		$ 241,867,000
Full cost ceiling impairments	$ 319,087,000		$ 0
Average depreciation and depletion rate (usd per Boe) | $ / Boe	8.31		7.92
Expected completion of evaluation activities on majority of unproved properties			10 years
Assets held for sale			$ 10,600,000
Successor | Drilling And Oil Field Services Assets
Property, Plant and Equipment [Line Items]
Assets held for sale			6,900,000
NRV of assets held-for-sale			2,900,000
Impairment recognized			4,000,000
Assets disposed of			1,700,000
Successor | Property Located in Oklahoma City, OK
Property, Plant and Equipment [Line Items]
Assets held for sale			$ 9,300,000

Property, Plant and Equipment75

Property, Plant and Equipment - Capitalized Costs of Unproved Properties Excluded from Amortization (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Property, Plant and Equipment [Line Items]
Property acquisition, cumulative	$ 96,450
Property acquisition	42,827	$ 15,610
Exploration, cumulative	4,434
Exploration	1,904	678
Total costs incurred, cumulative	100,884
Total costs incurred	$ 44,731	$ 16,288
Predecessor
Property, Plant and Equipment [Line Items]
Property acquisition, cumulative				$ 18,532
Property acquisition			$ 19,481
Exploration, cumulative				399
Exploration			1,453
Total costs incurred, cumulative				$ 18,931
Total costs incurred			$ 20,934

Impairment - Narrative (Details

Impairment - Narrative (Details) - USD ($)	3 Months Ended				9 Months Ended	12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015
Successor
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Full cost pool ceiling impairments	$ 319,087,000					$ 0
Asset impairment charges	319,087,000					4,019,000
Successor | Drilling assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges	0					4,019,000
Successor | Electrical infrastructure assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges	0					0
Successor | Midstream assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges	0					0
Successor | Other
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges	$ 0					$ 0
Predecessor
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Full cost pool ceiling impairments					$ 657,392,000		$ 4,473,787,000
Asset impairment charges		$ 354,500,000	$ 253,600,000	$ 110,100,000	718,194,000		4,534,689,000
Predecessor | Drilling assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges					3,511,000		37,646,000
Predecessor | Electrical infrastructure assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges					55,600,000		0
Predecessor | Midstream assets
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges					1,691,000		7,148,000
Predecessor | Other
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges					$ 0		16,108,000
Predecessor | Oklahoma City, Oklahoma | Other
Schedule of Impaired Long-Lived Assets Held and Used and Intangible Assets [Line Items]
Asset impairment charges							$ 15,400,000

Accounts Payable and Accrued 77

Accounts Payable and Accrued Expenses (Details) - Successor - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Schedule of Accounts Payable and Accrued Liabilities [Line Items]
Accounts payable and other accrued expenses	$ 94,406	$ 65,408
Accrued interest	1,385	648
Production payable	18,059	16,011
Payroll and benefits	21,475	33,606
Drilling advances	3,830	844
Total accounts payable and accrued expenses	$ 139,155	$ 116,517

Long-Term Debt (Details)

Long-Term Debt (Details) - Successor - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Total debt	$ 37,502	$ 305,308
Less: current maturities of long-term debt	0	0
Long-term debt	37,502	305,308
Revolving Credit Facility | New First Lien Exit Facility
Debt Instrument [Line Items]
Total debt	0	0
Convertible Debt | Convertible Notes
Debt Instrument [Line Items]
Total debt	0	268,780
Secured Debt | Building Note
Debt Instrument [Line Items]
Total debt	$ 37,502	$ 36,528

Long-Term Debt - Narrative (Det

Long-Term Debt - Narrative (Details) - Successor shares in Millions	Feb. 10, 2017USD ($)shares	Oct. 01, 2016USD ($)shares	Oct. 01, 2016USD ($)	Feb. 28, 2017shares	Feb. 09, 2017USD ($)shares	Dec. 31, 2016USD ($)shares	Feb. 09, 2017shares	May 11, 2017	Dec. 31, 2017USD ($)
Debt Instrument [Line Items]
Face value of long-term debt						$ 305,308,000			$ 37,502,000
Common stock issued for debt						13,001,000			268,779,000
Long-term debt maturing in 2021									36,300,000
Senior credit facility
Debt Instrument [Line Items]
Letters of credit outstanding									6,700,000
Secured Debt | Building Note
Debt Instrument [Line Items]
Face value of long-term debt						36,528,000			37,502,000
Face amount of debt instrument		$ 35,000,000	$ 35,000,000
Fair value of debt		36,600,000	$ 36,600,000
Term of paid in kind interest payments								90 days
Proceeds from issuance of debt		$ 26,800,000
Secured Debt | Building Note | October 5, 2016 through October 4, 2017
Debt Instrument [Line Items]
Annual interest rate		6.00%	6.00%
Secured Debt | Building Note | October 5, 2017 through October 4, 2018
Debt Instrument [Line Items]
Annual interest rate		8.00%	8.00%
Secured Debt | Building Note | October 5, 2018 and thereafter
Debt Instrument [Line Items]
Annual interest rate		10.00%	10.00%
Convertible Debt | Convertible Notes
Debt Instrument [Line Items]
Face value of long-term debt						268,780,000			0
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
Conversion ratio		0.05330841
Common stock issued for debt					$ 5,100,000	$ 13,000,000
Common stock issued for debt (in shares) | shares	14.1	15		14.1	0.3	0.7	1
Debt conversion, original debt, amount	$ 263,700,000
Annual interest rate		0.00%	0.00%
Revolving Credit Facility | New First Lien Exit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity		$ 425,000,000	$ 425,000,000
Line of credit facility, unused capacity, commitment fee percentage			0.50%
Cash collateral account	50,000,000
Face value of long-term debt						$ 0			0
Revolving Credit Facility | New First Lien Exit Facility | Base Rate
Debt Instrument [Line Items]
Basis spread on variable rate			3.75%
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%
Revolving Credit Facility | Amended New Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity	600,000,000
Line of credit facility, current borrowing capacity	$ 425,000,000
Line of credit facility, unused capacity, commitment fee percentage	0.50%
Minimum collateral amount of proved oil and gas reserves representing the discounted present value of reserves used in borrowing base determination	95.00%
Ratio of Indebtedness to Assets	3.50
Minimum consolidated interest coverage ratio	2.25
Aggregate amount of default trigger	$ 25,000,000
Legal judgment default trigger	$ 25,000,000
Face value of long-term debt									$ 0
Revolving Credit Facility | Amended New Credit Facility | Base Rate | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate	2.00%
Revolving Credit Facility | Amended New Credit Facility | Base Rate | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate	3.00%
Revolving Credit Facility | Amended New Credit Facility | LIBOR | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate	3.00%
Revolving Credit Facility | Amended New Credit Facility | LIBOR | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate	4.00%

Derivatives - Narrative (Detail

Derivatives - Narrative (Details) $ in Thousands	3 Months Ended					9 Months Ended	12 Months Ended
	Dec. 31, 2017USD ($)institution	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Oct. 01, 2016USD ($)	Dec. 31, 2017USD ($)institution	Dec. 31, 2015USD ($)
Successor
Derivative Instruments and Hedging Activities Disclosures [Line Items]
(Gain) loss on derivative contracts	$ 21,900	$ 11,700	$ (23,500)	$ (34,200)	$ 25,652		$ (24,090)
Cash receipts on settlement of derivative contracts					7,698		$ 7,260
Number of counterparties to open derivative contracts | institution	7						7
Successor | Commodity Derivatives
Derivative Instruments and Hedging Activities Disclosures [Line Items]
(Gain) loss on derivative contracts					25,700		$ (24,100)
Cash receipts on settlement of derivative contracts					$ 7,700		$ 7,300
Predecessor
Derivative Instruments and Hedging Activities Disclosures [Line Items]
(Gain) loss on derivative contracts						$ 4,823		$ (73,061)
Cash receipts on settlement of derivative contracts						72,608		327,702
Predecessor | Commodity Derivatives
Derivative Instruments and Hedging Activities Disclosures [Line Items]
(Gain) loss on derivative contracts						4,800		(73,100)
Cash receipts on settlement of derivative contracts						72,600		$ 327,700
Derivative, cash received on early settlement						$ 17,900
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%

Derivatives - Offsetting Assets

Derivatives - Offsetting Assets and Liabilities (Details) - Successor - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
ASSETS
Derivative assets, gross amounts	$ 5,582
Derivative assets, gross amounts offset	(4,272)
Derivative assets, amounts net of offset	1,310
Derivative assets, financial collateral	0
Derivative assets, net amount	1,310
LIABILITIES
Derivative liabilities, gross amounts	18,467	$ 29,714
Derivative liabilities, gross amounts offset	(4,272)	0
Derivative liabilities, amount net of offset	14,195	29,714
Derivative liabilities, financial collateral	(14,195)	(29,714)
Derivative liabilities, net amount	0	0
Derivative contracts - current
ASSETS
Derivative assets, gross amounts	5,582
Derivative assets, gross amounts offset	(4,272)
Derivative assets, amounts net of offset	1,310
Derivative assets, financial collateral	0
Derivative assets, net amount	1,310
Derivative contracts - noncurrent
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
Derivative contracts - current
LIABILITIES
Derivative liabilities, gross amounts	14,899	27,538
Derivative liabilities, gross amounts offset	(4,272)	0
Derivative liabilities, amount net of offset	10,627	27,538
Derivative liabilities, financial collateral	(10,627)	(27,538)
Derivative liabilities, net amount	0	0
Derivative contracts - noncurrent
LIABILITIES
Derivative liabilities, gross amounts	3,568	2,176
Derivative liabilities, gross amounts offset	0	0
Derivative liabilities, amount net of offset	3,568	2,176
Derivative liabilities, financial collateral	(3,568)	(2,176)
Derivative liabilities, net amount	$ 0	$ 0

Derivatives - Open Commodity De

Derivatives - Open Commodity Derivative Contracts (Details) - Successor	12 Months Ended
	Dec. 31, 2017$ / Mcf$ / bblMBblsMMcf
Oil Price Swaps, January 2018 - December 2018
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional (Oil in MBbl/Natural Gas in MMcf) | MBbls	3,464
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / bbl	55.08
Oil Price Swaps, January 2019 - December 2019
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional (Oil in MBbl/Natural Gas in MMcf) | MBbls	1,460
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / bbl	53.34
Natural Gas Price Swaps, January 2018 - December 2018
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional (Oil in MBbl/Natural Gas in MMcf) | MMcf	17,300
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / Mcf	3.16

Derivatives - Fair Value of Der

Derivatives - Fair Value of Derivative Contracts (Details) - Successor - USD ($)	Dec. 31, 2017	Dec. 31, 2016
Derivatives, Fair Value [Line Items]
Assets	$ 5,582,000
Derivative liabilities	(18,467,000)	$ (29,714,000)
Total net derivative contracts	(12,885,000)	(29,714,000)
Derivative contracts - current
Derivatives, Fair Value [Line Items]
Assets	5,582,000
Derivative contracts - noncurrent
Derivatives, Fair Value [Line Items]
Assets	0
Derivative contracts - current
Derivatives, Fair Value [Line Items]
Derivative liabilities	(14,899,000)	(27,538,000)
Derivative contracts - noncurrent
Derivatives, Fair Value [Line Items]
Derivative liabilities	(3,568,000)	(2,176,000)
Oil price swaps | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Assets	0	0
Oil price swaps | Derivative contracts - noncurrent
Derivatives, Fair Value [Line Items]
Assets	0	0
Oil price swaps | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Derivative liabilities	(14,899,000)	(13,395,000)
Oil price swaps | Derivative contracts - noncurrent
Derivatives, Fair Value [Line Items]
Derivative liabilities	(3,568,000)	(2,105,000)
Natural gas price swaps | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Assets	5,582,000	0
Natural gas price swaps | Derivative contracts - noncurrent
Derivatives, Fair Value [Line Items]
Assets	0	0
Natural gas price swaps | Derivative contracts - current
Derivatives, Fair Value [Line Items]
Derivative liabilities	0	(14,143,000)
Natural gas price swaps | Derivative contracts - noncurrent
Derivatives, Fair Value [Line Items]
Derivative liabilities	$ 0	$ (71,000)

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, 2017	Dec. 31, 2015
Successor
Asset Retirement Obligation, Roll Forward Analysis
Beginning balance	$ 92,413		$ 106,481
Liability incurred upon acquiring and drilling wells	121		1,336
Revisions in estimated cash flows	12,397		(28,565)
Liability settled or disposed in current period	(540)		(11,308)
Accretion	2,090		9,600
Impact of fresh start accounting	0		0
Ending balance	106,481	$ 92,413	77,544
Less: current portion	66,154		41,017
Asset retirement obligations, net of current	40,327		$ 36,527
Predecessor
Asset Retirement Obligation, Roll Forward Analysis
Beginning balance	$ 92,413	103,578		$ 54,402
Liability incurred upon acquiring and drilling wells		505		1,662
Revisions in estimated cash flows		0		44,060
Liability settled or disposed in current period		(36,979)		(1,023)
Accretion		4,365		4,477
Impact of fresh start accounting		20,944		0
Ending balance		92,413		103,578
Less: current portion		65,678		8,399
Asset retirement obligations, net of current		26,735		$ 95,179
Predecessor | WTO Properties
Asset Retirement Obligation, Roll Forward Analysis
Liability settled or disposed in current period		$ (34,100)

Commitments and Contingencies -

Commitments and Contingencies - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015
Predecessor
Commitments and Contingencies Disclosure [Line Items]
Employee termination benefits		$ 18,356		$ 12,451
Successor
Commitments and Contingencies Disclosure [Line Items]
Employee termination benefits	$ 12,334		$ 4,815
Employee Severance | Predecessor
Commitments and Contingencies Disclosure [Line Items]
Employee termination benefits		$ 18,400		$ 12,500
Employee Severance | Successor
Commitments and Contingencies Disclosure [Line Items]
Employee termination benefits	$ 12,300		$ 4,800

Equity - Successor Equity (Deta

Equity - Successor Equity (Details) - USD ($) $ / shares in Units, $ in Millions	Jan. 22, 2018	Feb. 10, 2017	Oct. 01, 2016	Feb. 28, 2017	Feb. 09, 2017	Dec. 31, 2016	Feb. 09, 2017	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015	Jun. 30, 2015
Successor
Class of Stock [Line Items]
Common stock, issued (in shares)						21,042,000			35,650,000
Common stock, par value (in dollars per share)						$ 0.001			$ 0.001
Shares authorized (in shares)						250,000,000			250,000,000
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
Shares issued									100,000
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						100,000
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
Successor | Series A and Series B Warrant [Member]
Class of Stock [Line Items]
Class of Warrant, Number of Securities issued for Each Warrant			1					1
Successor | Convertible Notes | Convertible Debt
Class of Stock [Line Items]
Common stock issued for debt (in shares)		14,100,000	15,000,000	14,100,000	300,000	700,000	1,000,000
Debt conversion, original debt, amount		$ 263.7
Predecessor
Class of Stock [Line Items]
Shares held in treasury (in shares)										2,100,000
Predecessor | 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								$ 232.1		$ 255.3
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
Predecessor | Minimum | Common Stock
Class of Stock [Line Items]
Shares authorized (in shares)											800,000,000
Predecessor | Minimum | Convertible Perpetual 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 | Convertible Perpetual 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
Subsequent Event [Member]
Class of Stock [Line Items]
Beneficial ownership percentage by person or group of persons required to trigger shareholder rights plan	15.00%

Equity - Shares Withheld for Ta

Equity - Shares Withheld for Taxes (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2017
Successor
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Value of shares withheld for taxes	$ 110	$ 6,730

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

Equity - Treasury Stock Activit

Equity - Treasury Stock Activity (Details) - Treasury Stock - USD ($) shares in Thousands, $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015	Dec. 31, 2014
Successor
Equity, Class of Treasury Stock [Line Items]
Number of shares withheld for taxes	5		349
Value of shares withheld for taxes	$ 110		$ 6,730
Number of shares retired	5		349
Value of shares retired	$ 110		$ 6,730
Predecessor
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 - Narr

Share Based Compensation - Narrative (Details) $ in Millions	1 Months Ended		3 Months Ended	9 Months Ended	12 Months Ended
	Feb. 28, 2017shares	Oct. 31, 2016$ / Unitshares	Dec. 31, 2016USD ($)shares	Oct. 01, 2016USD ($)shares	Dec. 31, 2017USD ($)shares	Dec. 31, 2015USD ($)shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized | shares				4,600,000
Successor
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period of employee incentive plan		3 years
Weighted average grant date fair value | $ / Unit		100
Liability related to performance units					$ 3.1
Compensation expense related to performance units					2.6
Capitalized compensation expense related to performance units					$ 0.4
Successor | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted | shares		1,400,000	1,448,000		671,000
Vesting period (in years)		3 years			2 years 6 months
Share-based compensation expense			$ 6.6		$ 16.6
Share-based compensation, capitalized			0.3		2
Severance, compensation cost of accelerated shares			$ 4.3		$ 1.8
Severance, number of accelerated shares | shares			200,000		100,000
Unrecognized compensation cost related to unvested awards					$ 21.4
Period of recognition for unrecognized costs					1 year 9 months 18 days
Aggregate intrinsic value of restricted stock vested during period					$ 16
Successor | Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense					1.4
Share-based compensation, capitalized					$ 0.2
Performance share plan, conversion to common stock | shares	1
Predecessor
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense				$ 11.2		$ 21.7
Share-based compensation, capitalized				1.7		$ 5.9
Unrecognized compensation cost related to unvested awards				$ 5.9
Predecessor | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted | shares				0		2,928,000
Vesting period (in years)				4 years
Severance, compensation cost of accelerated shares				$ 5.4
Severance, number of accelerated shares | shares				1,300,000
Maximum | Successor | Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted | shares	400,000

Share Based Compensation - Summ

Share Based Compensation - Summary of Unvested Restricted Stock Awards (Details) - Restricted Stock - $ / shares shares in Thousands	1 Months Ended	3 Months Ended	9 Months Ended	12 Months Ended
	Oct. 31, 2016	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015
Successor
Number of Shares
Unvested shares/units outstanding at beginning of period	0	0		1,407
Granted (in shares)	1,400	1,448		671
Vested (in shares)		(14)		(827)
Forfeited / Canceled (in shares)		(27)		(146)
Unvested shares/units outstanding at end of period		1,407	0	1,105
Weighted- Average Grant Date Fair Value (usd per share)
Unvested restricted shares outstanding at beginning of period (in usd per share)	$ 0	$ 0		$ 24.32
Granted (in usd per share)		24.32		19.97
Vested (in usd per share)		24.32		23.23
Forfeited / Canceled (in usd per share)		24.32		23.52
Unvested restricted shares outstanding at end of period (in usd per share)		$ 24.32	$ 0	$ 22.62
Predecessor
Number of Shares
Unvested shares/units outstanding at beginning of period	0	0	5,626		8,556
Granted (in shares)			0		2,928
Vested (in shares)			(3,034)		(5,186)
Forfeited / Canceled (in shares)			(2,592)		(672)
Unvested shares/units outstanding at end of period			0		5,626
Weighted- Average Grant Date Fair Value (usd per share)
Unvested restricted shares outstanding at beginning of period (in usd per share)	$ 0	$ 0	$ 4.85		$ 6.39
Granted (in usd per share)			0		0.88
Vested (in usd per share)			5.34		4.95
Forfeited / Canceled (in usd per share)			4.31		6.38
Unvested restricted shares outstanding at end of period (in usd per share)			$ 0		$ 4.85

Incentive and Deferred Compen93

Incentive and Deferred Compensation Plans (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended	9 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016	Jun. 30, 2016	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015	Jan. 31, 2016
Successor
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Deferred compensation plan assets to be distributed to participants					$ 5.1
Successor | Other Postretirement Benefits Plan
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%
Retirement plan, employer matching contribution, vesting period		4 years			4 years
Retirement plan, employer matching contribution, percent of employees' gross pay (up to)		10.00%			10.00%
Retirement plan, cost recognized		$ 0.9			$ 3.6
Percent of employee contributions vesting immediately		100.00%			100.00%
Successor | Annual Incentive Plan
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Accrued bonuses					$ 10.8
Successor | Annual 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%
Successor | Annual 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 | Performance Incentive Plan
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Payments to employees	$ 15.8	$ 7.1
Predecessor | Other Postretirement Benefits Plan
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%
Retirement plan, employer matching contribution, vesting period				4 years		4 years
Retirement plan, employer matching contribution, percent of employees' gross pay (up to)				10.00%		10.00%
Retirement plan, cost recognized				$ 4.9		$ 7.9
Percent of employee contributions vesting immediately				100.00%		100.00%
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%

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, 2017	Dec. 31, 2015
Successor
Current
Federal	$ 0		$ (8,719)
State	9		(30)
Current, total	9		(8,749)
Deferred
Federal	0		0
State	0		0
Deferred, total	0		0
Total (benefit) provision	9		(8,749)
Successor | Noncontrolling Interest
Deferred
Total (benefit) provision	0		0
Successor | Parent
Deferred
Total (benefit) provision	$ 9		$ (8,749)
Predecessor
Current
Federal		$ 0		$ 0
State		11		123
Current, total		11		123
Deferred
Federal		0		0
State		0		0
Deferred, total		0		0
Total (benefit) provision		11		123
Predecessor | Noncontrolling Interest
Deferred
Total (benefit) provision		0		90
Predecessor | Parent
Deferred
Total (benefit) provision		$ 11		$ 33

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of (Benefit) Provision for Income Taxes at Statutory Federal Tax Rate to Company's Actual Income Tax (Benefit) Provision (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015
Successor
Reconciliation Of Provision Of Income Taxes [Line Items]
Release of valuation allowance			$ (8,700)
Total (benefit) provision	$ 9		(8,749)
Successor | Parent
Reconciliation Of Provision Of Income Taxes [Line Items]
Computed at federal statutory rate	(116,891)		13,409
State taxes, net of federal benefit	(3,696)		(284)
Non-deductible expenses	144		1,711
Non-deductible debt costs	0		0
Stock-based compensation	306		1,109
Net effects of consolidating the non-controlling interests’ tax provisions	0		0
Discharge of debt and other reorganization related items	0		1,018
Return to provision adjustments	0		341,681
Impact of legislative changes	0		243,801
Release of valuation allowance	0		(8,719)
Change in valuation allowance	120,144		(602,452)
Other	2		(23)
Total (benefit) provision	$ 9		$ (8,749)
Predecessor
Reconciliation Of Provision Of Income Taxes [Line Items]
Total (benefit) provision		$ 11		$ 123
Predecessor | Parent
Reconciliation Of Provision Of Income Taxes [Line Items]
Computed at federal statutory rate		504,283		(1,512,325)
State taxes, net of federal benefit		10,512		(19,988)
Non-deductible expenses		462		816
Non-deductible debt costs		22,694		10,228
Stock-based compensation		5,884		6,700
Net effects of consolidating the non-controlling interests’ tax provisions		0		218,196
Discharge of debt and other reorganization related items		359,278		0
Return to provision adjustments		0		0
Impact of legislative changes		0		0
Release of valuation allowance		0		0
Change in valuation allowance		(903,102)		1,296,405
Other		0		1
Total (benefit) provision		$ 11		$ 33

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating Loss Carryforwards [Line Items]
Expected expiration period of unrecognized tax benefits	12 months
Successor
Operating Loss Carryforwards [Line Items]
Release of AMT valuation allowance	$ (8,700)
Valuation allowance	500,949	$ 1,119,721
Income tax expense due to TCJA	243,800
Net deferred tax asset	0	$ 0
Successor | Alternative Minimum Tax Credit Carryforward
Operating Loss Carryforwards [Line Items]
Alternative minimum tax credits, not subject to expiration	$ 4,700
Successor | Earliest Tax Year
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards expiration year	2,025
Successor | Latest Tax Year
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards expiration year	2,037
Successor | Domestic Tax Authority
Operating Loss Carryforwards [Line Items]
Federal net operating loss carryovers	$ 805,300
Predecessor
Operating Loss Carryforwards [Line Items]
Valuation allowance			$ 2,000,000

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Assets and Liabilities (Details) - Successor - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Deferred tax liabilities
Investments	$ 171,517	$ 275,128
Total deferred tax liabilities	171,517	275,128
Deferred tax assets
Property, plant and equipment	391,273	751,683
Derivative contracts	3,131	11,274
Allowance for doubtful accounts	986	1,487
Net operating loss carryforwards	217,259	527,079
Compensation and benefits	5,700	14,494
Tax Credits and other carryforwards	33,001	43,770
Asset retirement obligations	18,843	40,399
Other	2,273	4,663
Total deferred tax assets	672,466	1,394,849
Valuation allowance	(500,949)	(1,119,721)
Net deferred tax liability	$ 0	$ 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, 2017
Successor
Reconciliation of Unrecognized Tax Benefits
Unrecognized tax benefit at January 1	$ 81		$ 84
Changes to unrecognized tax benefits related to a prior period	3		2
Lapse of statute of limitations	0		(38)
Unrecognized tax benefit at December 31	84	$ 81	$ 48
Predecessor
Reconciliation of Unrecognized Tax Benefits
Unrecognized tax benefit at January 1	$ 81	81
Changes to unrecognized tax benefits related to a prior period		0
Lapse of statute of limitations		0
Unrecognized tax benefit at December 31		$ 81

Income Taxes - Periods Open to

Income Taxes - Periods Open to Tax Examination (Details) - Successor	12 Months Ended
	Dec. 31, 2017
Domestic Tax Authority | Earliest Tax Year
Income Tax Contingency [Line Items]
Open tax year	2,014
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	2,013
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

Earnings (Loss) per Share - Cal

Earnings (Loss) per Share - Calculation of Weighted Average Common Shares Outstanding used in Computation of Diluted Earnings (Loss) Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	Oct. 01, 2016	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015
Successor
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net Income (Loss), Basic		$ (18,760)	$ (8,485)	$ 23,499	$ 50,808	$ (333,982)					$ 47,062
Weighted Average Shares, basic						18,967					32,442
Earnings (Loss) Per Share, Basic (in dollars per share)		$ (0.54)	$ (0.25)	$ 0.69	$ 1.90	$ (17.61)					$ 1.45
Effect of dilutive securities
Net Income (Loss), Restricted stock						$ 0					$ 0
Weighted Average Shares, Restricted stock						0					221
Net Income (Loss), Performance share units											$ 0
Weighted Average Shares, Performance share units											0
Net Income (Loss), Warrants						$ 0					$ 0
Weighted Average Shares, Warrants						0					0
Net Income (Loss), Convertible notes						$ 0
Weighted Average Shares, Convertible notes						0
Net Income (Loss), Diluted						$ (333,982)					$ 47,062
Weighted Average Shares, Diluted						18,967					32,663
Earnings (Loss) Per Share, Diluted (in dollars per share)		$ (0.54)	$ (0.25)	$ 0.69	$ 1.90	$ (17.61)					$ 1.44
Predecessor
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net Income (Loss), Basic	$ 2,674,271						$ (404,337)	$ (521,351)	$ (324,107)	$ 1,424,476		$ (3,735,495)
Weighted Average Shares, basic										708,928		521,936
Earnings (Loss) Per Share, Basic (in dollars per share)	$ 3.72						$ (0.56)	$ (0.73)	$ (0.47)	$ 2.01		$ (7.16)
Effect of dilutive securities
Net Income (Loss), Restricted stock										$ 0		$ 0
Weighted Average Shares, Restricted stock										0		0
Net Income (Loss), Convertible preferred stock												$ 0
Weighted Average Shares, Convertible preferred stock												0
Net Income (Loss), Diluted										$ 1,424,476		$ (3,735,495)
Weighted Average Shares, Diluted										708,928		521,936
Earnings (Loss) Per Share, Diluted (in dollars per share)	$ 3.72						$ (0.56)	$ (0.73)	$ (0.47)	$ 2.01		$ (7.16)

Earnings (Loss) per Share - 101

Earnings (Loss) per Share - Calculation of Weighted Average Common Shares Outstanding used in Computation of Diluted Earnings (Loss) Per Share (Additional Information) (Details) - shares	Oct. 01, 2016	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015
Successor | Performance Share Units
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share				0
Successor | Restricted Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share		0
Successor | 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 | Warrants
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share		0		0
Predecessor | Restricted Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share			0		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
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 | Restricted Stock Units (RSUs) [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share			0		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 | 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%

Supplemental Information on 102

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, 2017	Dec. 31, 2016	Dec. 31, 2015
Successor
Oil and natural gas properties
Proved	$ 1,056,806	$ 840,201
Unproved	100,884	74,937
Total oil and natural gas properties	1,157,690	915,138
Less: accumulated depreciation, depletion and impairment	(460,431)	(353,030)
Net oil and natural gas properties capitalized costs	$ 697,259	$ 562,108
Predecessor
Oil and natural gas properties
Proved			$ 12,529,681
Unproved			363,149
Total oil and natural gas properties			12,892,830
Less: accumulated depreciation, depletion and impairment			(11,149,888)
Net oil and natural gas properties capitalized costs			$ 1,742,942

Supplemental Information on 103

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, 2017	Dec. 31, 2015
Successor
Acquisitions of properties
Proved	$ 5,142		$ 7,092
Unproved	5,491		91,139
Exploration	0		8,850
Development	27,429		187,264
Total cost incurred	$ 38,062		$ 294,345
Predecessor
Acquisitions of properties
Proved		$ 3,897		$ 35,376
Unproved		1,899		210,065
Exploration		1,234		29,297
Development		149,924		571,562
Total cost incurred		$ 156,954		846,300
Predecessor | Seismic Costs
Acquisitions of properties
Exploration				$ 7,100

Supplemental Information on 104

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, 2017	Dec. 31, 2015
Successor
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Revenues	$ 98,307		$ 356,210
Expenses
Production costs	27,640		116,372
Depreciation and depletion	36,061		118,035
Impairment	319,087		0
Total expenses	382,788		234,407
Income (loss) before income taxes	(284,481)		121,803
Income tax expense (benefit)	(112,427)		47,722
Results of operations for oil and natural gas producing activities (excluding corporate overhead and interest costs)	$ (172,054)		$ 74,081
Predecessor
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Revenues		$ 279,971		$ 707,434
Expenses
Production costs		135,715		324,141
Depreciation and depletion		90,978		324,390
Impairment		657,392		4,473,787
Total expenses		884,085		5,122,318
Income (loss) before income taxes		(604,114)		(4,414,884)
Income tax expense (benefit)		(229,986)		(1,680,746)
Results of operations for oil and natural gas producing activities (excluding corporate overhead and interest costs)		$ (374,128)		$ (2,734,138)

Supplemental Information on 105

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, 2016MBoeMBblsMcf	Oct. 01, 2016MBoeMBblsMcf	Dec. 31, 2017MBoeMBblsMcf	Dec. 31, 2016MBoeMBblsMcf	Dec. 31, 2015MBoeMBblsMcf	Dec. 31, 2014MBoeMBblsMcf
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Revisions of previous estimates (MBoe) | MBoe				(105,400)
Extensions and discoveries (MBoe) | MBoe				7,800
Sales of reserves in place (MBoe) | MBoe				(24,600)
Predecessor
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Proved developed and undeveloped reserves, Beginning balance (MBoe) | MBoe	137,992	324,626		324,626	515,856
Adoption of ASU 2015-02 (MBoe) | MBoe		(19,084)
Revisions of previous estimates (MBoe) | MBoe		(130,709)			(234,610)
Acquisitions of new reserves (MBoe) | MBoe					27,566
Extensions and discoveries (MBoe) | MBoe		2,785			45,809
Sales of reserves in place (MBoe) | MBoe		(24,598)
Production (MBoe) | MBoe		(15,027)			(29,995)
Proved developed and undeveloped reserves, Ending balance (MBoe) | MBoe		137,992			324,626
Proved developed reserves (MBoe) | MBoe		126,121			260,498	336,420
Proved undeveloped reserves (MBoe) | MBoe		11,872			64,129	179,436
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		77,911	126,031
Adoption of ASU 2015-02		(6,971)
Revisions of previous estimates		(39,973)			(70,708)
Acquisitions of new reserves					22,447
Extensions and discoveries		987			9,741
Sales of reserves in place		(387)
Production		(4,315)			(9,600)
Proved developed and undeveloped reserves, ending balance		27,252			77,911
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)		24,541			48,639	79,022
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)		2,711			29,272	47,009
Predecessor | 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		7,004	11,027
Proved developed and undeveloped reserves, ending balance					7,004
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		61,075	91,786
Adoption of ASU 2015-02		(3,695)
Revisions of previous estimates		(21,475)			(37,384)
Acquisitions of new reserves					2,460
Extensions and discoveries		472			9,257
Sales of reserves in place		0
Production		(3,358)			(5,044)
Proved developed and undeveloped reserves, ending balance		33,019			61,075
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)		30,238			51,089	56,823
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)		2,781			9,986	34,963
Predecessor | 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		3,694	4,761
Proved developed and undeveloped reserves, ending balance					3,694
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		1,113,840	1,788,233
Adoption of ASU 2015-02 | Mcf		(50,508)
Revisions of previous estimates | Mcf		(415,568)			(759,106)
Acquisitions of new reserves | Mcf					15,952
Extensions and discoveries | Mcf		7,955			160,865
Sales of reserves in place | Mcf		(145,267)
Production | Mcf		(44,124)			(92,104)
Proved developed and undeveloped reserves, ending balance | Mcf		466,328			1,113,840
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas) | Mcf		428,050			964,617	1,203,447
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas) | Mcf		38,278			149,223	584,786
Predecessor | 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		50,508	70,833
Proved developed and undeveloped reserves, ending balance | Mcf					50,508
Successor
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Proved developed and undeveloped reserves, Beginning balance (MBoe) | MBoe			163,955
Revisions of previous estimates (MBoe) | MBoe	25,270		10,879
Acquisitions of new reserves (MBoe) | MBoe			202
Extensions and discoveries (MBoe) | MBoe	5,034		19,373
Sales of reserves in place (MBoe) | MBoe			(1,909)
Production (MBoe) | MBoe	(4,341)		(14,906)
Proved developed and undeveloped reserves, Ending balance (MBoe) | MBoe	163,955		177,594	163,955
Proved developed reserves (MBoe) | MBoe	120,706		123,765	120,706
Proved undeveloped reserves (MBoe) | MBoe	43,249		53,829	43,249
Successor | Oil
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Proved developed and undeveloped reserves, beginning balance			52,884
Revisions of previous estimates	23,978		804
Acquisitions of new reserves			18
Extensions and discoveries	2,868		12,446
Sales of reserves in place			(204)
Production	(1,214)		(4,157)
Proved developed and undeveloped reserves, ending balance	52,884		61,791	52,884
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	25,911		25,845	25,911
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	26,973		35,946	26,973
Successor | NGL
Proved Developed and Undeveloped Reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)
Proved developed and undeveloped reserves, beginning balance			33,607
Revisions of previous estimates	1,139		2,628
Acquisitions of new reserves			70
Extensions and discoveries	448		1,914
Sales of reserves in place			(529)
Production	(999)		(3,376)
Proved developed and undeveloped reserves, ending balance	33,607		34,314	33,607
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	29,290		29,922	29,290
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas)	4,317		4,392	4,317
Successor | 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			464,782
Revisions of previous estimates | Mcf	915		44,679
Acquisitions of new reserves | Mcf			683
Extensions and discoveries | Mcf	10,309		30,080
Sales of reserves in place | Mcf			(7,055)
Production | Mcf	(12,770)		(44,237)
Proved developed and undeveloped reserves, ending balance | Mcf	464,782		488,932	464,782
Proved developed reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas) | Mcf	393,028		407,988	393,028
Proved undeveloped reserves (in MBbls for Oil and NGLs/MMcf for Natural Gas) | Mcf	71,754		80,944	71,754

Supplemental Information on 106

Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited) - Calculation of Weighted Average Per Unit Prices (Unaudited) (Details)	12 Months Ended
	Dec. 31, 2017$ / Mcf$ / bbl	Dec. 31, 2016$ / Mcf$ / bbl	Dec. 31, 2015$ / 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)	48.47	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)	20.28	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	1.90	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
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
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

Supplemental Information on 107

Supplemental Information on Oil and Natural Gas Producing Activities (Unaudited) - Standardized Measure of Discounted Future Cash Flows (Unaudited) (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Oct. 01, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future cash inflows from production	$ 4,621,615	$ 3,136,762
Future production costs	(1,837,852)	(1,454,798)
Future development costs	(966,203)	(665,516)
Future income tax expenses	(107)	(142)
Undiscounted future net cash flows	1,817,453	1,016,306
10% annual discount	(1,068,159)	(577,942)
Standardized measure of discounted future net cash flows	$ 749,294	$ 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
Future production costs				(2,731,542)
Future development costs				(838,945)
Future income tax expenses				(901)
Undiscounted future net cash flows				2,816,556
10% annual discount				(1,501,994)
Standardized measure of discounted future net cash flows			$ 392,604	1,314,562	$ 4,087,752
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

Supplemental Information on 108

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, 2017	Dec. 31, 2015
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		$ 438,364
Changes during the year
Adoption of ASU 2015-02	0		0
Revenues less production	(70,668)		(239,838)
Net changes in prices, production and other costs	35,684		347,458
Development costs incurred	7,941		35,517
Net changes in future development costs	(291,232)		(64,484)
Extensions and discoveries	14,986		112,556
Revisions of previous quantity estimates	308,374		26,697
Accretion of discount	9,375		37,226
Net change in income taxes	0		23
Purchases of reserves in-place	0		454
Sales of reserves in-place	0		(2,977)
Timing differences and other	31,300		58,298
Net change for the year	45,760		310,930
Present value, ending balance	438,364	$ 392,604	$ 749,294
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
Changes during the year
Adoption of ASU 2015-02		(224,965)		0
Revenues less production		(144,256)		(383,293)
Net changes in prices, production and other costs		(394,173)		(3,813,465)
Development costs incurred		69,080		217,596
Net changes in future development costs		436,041		273,437
Extensions and discoveries		12,449		230,055
Revisions of previous quantity estimates		(728,254)		(1,354,778)
Accretion of discount		91,337		512,483
Net change in income taxes		402		1,426,333
Purchases of reserves in-place		0		18,429
Sales of reserves in-place		(13,314)		0
Timing differences and other		(26,305)		100,013
Net change for the year		(921,958)		(2,773,190)
Present value, ending balance		392,604		1,314,562
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
Changes during the year
Present value, ending balance				$ 224,600

Supplemental Information on 109

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, 2016MBoeMBblsMcf	Oct. 01, 2016MBoeMBblsMcf	Dec. 31, 2017MBoewellMBblsMcf	Dec. 31, 2016MBoe	Dec. 31, 2015MBoeMMBoeMBblsMcf
Reserve Quantities [Line Items]
Upward revision of estimates due to extensions (MBoe) | MBoe				7,800
Decrease in reserves due to sale (MBoe) | MBoe				24,600
Revision of previous estimates (MBoe) | MBoe				(105,400)
Revision of previous estimates due to changes in well performance (MBoe) | MBoe				94,700
Revision of previous estimates due to changes in commodity pricing (MBoe) | MBoe				12,100
Decrease in reserves due to changes in accounting | MBoe				19,100
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%
Mid-Continent
Reserve Quantities [Line Items]
Minimum number of wells in areas with decline in production | well			3
Number of years wells in production seeing decline in production			2 years
Successor
Reserve Quantities [Line Items]
Upward revision of estimates due to extensions (MBoe) | MBoe	5,034		19,373
Decrease in reserves due to sale (MBoe) | MBoe			1,909
Revision of previous estimates (MBoe) | MBoe	25,270		10,879
Acquisitions of new reserves (MBoe) | MBoe			202
Successor | Oil
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas) | MBbls	2,868		12,446
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | MBbls	23,978		804
Successor | Natural Gas
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf	10,309		30,080
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf	915		44,679
Successor | NGL
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas) | MBbls	448		1,914
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | MBbls	1,139		2,628
Predecessor
Reserve Quantities [Line Items]
Upward revision of estimates due to extensions (MBoe) | MBoe		2,785			45,809
Decrease in reserves due to sale (MBoe) | MBoe		24,598
Revision of previous estimates (MBoe) | MBoe		(130,709)			(234,610)
Acquisitions of new reserves (MBoe) | MBoe					27,566
Predecessor | Oil
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas) | MBbls		987			9,741
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | MBbls		(39,973)			(70,708)
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
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | Mcf		(415,568)			(759,106)
Predecessor | NGL
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas) | MBbls		472			9,257
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | MBbls		(21,475)			(37,384)
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) | MBbls					(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) | MBbls					(36,000)
Predecessor | Mid-Continent | Oil
Reserve Quantities [Line Items]
Extensions and discoveries (in MBbls for Oil and NGLs/Mcf for Natural Gas) | MBbls					9,700
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | MBbls					(16,000)
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) | MBbls					9,300
Positive (negative) Revisions of previous estimates (in MBbls for Oil and NGLs/Mcf for Natural Gas) | MBbls					(1,000)
Predecessor | North Park Basin, Jackson County, Colorado [Member]
Reserve Quantities [Line Items]
Acquisitions of new reserves (MBoe) | MMBoe					27.6

Quarterly Financial Results 110

Quarterly Financial Results (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Thousands	Oct. 01, 2016	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Oct. 01, 2016	Dec. 31, 2017	Dec. 31, 2015
Successor
Quarterly Financial Information [Line Items]
Total revenues		$ 93,206	$ 80,892	$ 84,851	$ 98,350	$ 98,456					$ 357,299
Income (loss) from operations		(18,230)	(16,267)	23,348	50,780	(336,345)					39,631
Net (loss) income		(18,760)	(8,485)	23,499	50,808	(333,982)					47,062
(Loss applicable) income available to SandRidge Energy, Inc. common stockholders		$ (18,760)	$ (8,485)	$ 23,499	$ 50,808	$ (333,982)					$ 47,062
Income available (loss applicable) per share to SandRidge Energy, Inc. common stockholders
Basic (in dollars per share)		$ (0.54)	$ (0.25)	$ 0.69	$ 1.90	$ (17.61)					$ 1.45
Diluted (in dollars per share)		$ (0.54)	$ (0.25)	$ 0.69	$ 1.90	$ (17.61)					$ 1.44
(Gain) loss on derivative contracts		$ 21,900	$ 11,700	$ (23,500)	$ (34,200)	$ 25,652					$ (24,090)
Terminated merger costs		$ 8,200				0					8,162
Impairment						319,087					4,019
Loss on settlement of contract						0					0
Gain on extinguishment of debt						$ 0					$ 0
Predecessor
Quarterly Financial Information [Line Items]
Total revenues	$ 0						$ 104,056	$ 99,421	$ 90,332	$ 293,809		$ 768,709
Income (loss) from operations	0						(357,338)	(275,310)	(273,555)	(906,203)		(4,642,678)
Net (loss) income	2,674,271						(404,337)	(515,911)	(313,226)	1,440,797		(4,321,051)
(Loss applicable) income available to SandRidge Energy, Inc. common stockholders	$ 2,674,271						$ (404,337)	$ (521,351)	$ (324,107)	$ 1,424,476		$ (3,735,495)
Income available (loss applicable) per share to SandRidge Energy, Inc. common stockholders
Basic (in dollars per share)	$ 3.72						$ (0.56)	$ (0.73)	$ (0.47)	$ 2.01		$ (7.16)
Diluted (in dollars per share)	$ 3.72						$ (0.56)	$ (0.73)	$ (0.47)	$ 2.01		$ (7.16)
(Gain) loss on derivative contracts										$ 4,823		$ (73,061)
Terminated merger costs										0		0
Impairment							$ 354,500	$ 253,600	$ 110,100	718,194		4,534,689
Loss on settlement of contract									89,100	90,184		50,976
Gain on extinguishment of debt									$ 41,300	$ 41,179		$ 641,131
Gain (loss) on reorganization items	$ 2,700,000						$ (42,800)	$ (200,900)

Uncategorized Items - sd10-k123

Label	Element	Value
Predecessor [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ (1,250,000)
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	575,163,000
Stock Issued During Period, Value, Warrants	sd_StockIssuedDuringPeriodValueWarrants	88,382,000
Additional Paid-in Capital [Member] | Predecessor [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	5,314,405,000
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
Treasury Stock [Member] | Predecessor [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(5,218,000)
Noncontrolling Interest [Member] | Predecessor [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(21,000)
Retained Earnings [Member] | Predecessor [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ (5,311,140,000)
Common Stock [Member] | Predecessor [Member]
Common Stock, Shares, Outstanding	us-gaap_CommonStockSharesOutstanding	718,500,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ 718,000
Stock Issued During Period, Shares, New Issues	us-gaap_StockIssuedDuringPeriodSharesNewIssues	18,932,000
Stock Issued During Period, Value, New Issues	us-gaap_StockIssuedDuringPeriodValueNewIssues	$ 19,000
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