SandRidge Energy (SD) 10-Q 6 Aug 15 2015 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2015	Jul. 31, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	SANDRIDGE ENERGY INC
Trading Symbol	SD
Entity Central Index Key	1,349,436
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		518,204,476

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Current assets
Cash and cash equivalents	$ 983,617	$ 181,253
Accounts receivable, net	237,720	330,077
Derivative contracts	120,575	291,414
Prepaid expenses	9,938	7,981
Other current assets	25,985	21,193
Total current assets	1,377,835	831,918
Oil and natural gas properties, using full cost method of accounting
Proved	12,199,049	11,707,147
Unproved	261,657	290,596
Less: accumulated depreciation, depletion and impairment	(9,131,153)	(6,359,149)
Net oil and natural gas properties capitalized costs	3,329,553	5,638,594
Other property, plant and equipment, net	556,848	576,463
Derivative contracts	23,470	47,003
Other assets	147,342	165,247
Total assets	5,435,048	7,259,225
Current liabilities
Accounts payable and accrued expenses	494,675	683,392
Derivative contracts	102	0
Deferred tax liability	52,763	95,843
Other current liabilities	3,791	5,216
Total current liabilities	551,331	784,451
Long-term debt	4,395,639	3,195,436
Derivative contracts	26	0
Asset retirement obligations	57,084	54,402
Other long-term obligations	15,396	15,116
Total liabilities	$ 5,019,476	$ 4,049,405
Commitments and contingencies (Note 10)
Preferred stock, $0.001 par value, 50,000 shares authorized
Common stock, $0.001 par value; 1,800,000 shares authorized, 519,269 issued and 517,958 outstanding at June 30, 2015; 800,000 shares authorized, 485,932 issued and 484,819 outstanding at December 31, 2014	$ 514	$ 477
Additional paid-in capital	5,252,785	5,204,024
Additional paid-in capital—stockholder receivable	(2,500)	(2,500)
Treasury stock, at cost	(6,776)	(6,980)
Accumulated deficit	(5,678,592)	(3,257,202)
Total SandRidge Energy, Inc. stockholders’ equity	(434,563)	1,937,825
Noncontrolling interest	850,135	1,271,995
Total equity	415,572	3,209,820
Total liabilities and equity	5,435,048	7,259,225
8.5% Convertible perpetual preferred stock; 2,650 shares issued and outstanding at June 30, 2015 and December 31, 2014; aggregate liquidation preference of $265,000
Preferred stock, $0.001 par value, 50,000 shares authorized
Preferred stock	3	3
7.0% Convertible perpetual preferred stock; 3,000 shares issued and outstanding at June 30, 2015 and December 31, 2014; aggregate liquidation preference of $300,000
Preferred stock, $0.001 par value, 50,000 shares authorized
Preferred stock	$ 3	$ 3

CONDENSED CONSOLIDATED BALANCE3

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Preferred stock, par value (in dollars per share)	$ 0.001	$ 0.001
Preferred stock, shares authorized	50,000,000	50,000,000
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares authorized	1,800,000,000	800,000,000
Common stock, issued (in shares)	519,269,000	485,932,000
Common stock, outstanding (in shares)	517,958,000	484,819,000
8.5% Convertible perpetual preferred stock; 2,650 shares issued and outstanding at June 30, 2015 and December 31, 2014; aggregate liquidation preference of $265,000
Preferred stock, shares issued (in shares)	2,650,000	2,650,000
Preferred stock, shares outstanding	2,650,000	2,650,000
Preferred stock, aggregate liquidation preference	$ 265,000	$ 265,000
7.0% Convertible perpetual preferred stock; 3,000 shares issued and outstanding at June 30, 2015 and December 31, 2014; aggregate liquidation preference of $300,000
Preferred stock, shares issued (in shares)	3,000,000	3,000,000
Preferred stock, shares outstanding	3,000,000	3,000,000
Preferred stock, aggregate liquidation preference	$ 300,000	$ 300,000

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues
Oil, natural gas and NGL	$ 214,532	$ 339,906	$ 410,264	$ 745,222
Drilling and services	5,241	18,852	15,086	35,932
Midstream and marketing	8,606	14,874	17,370	32,784
Other	1,228	1,082	2,195	3,832
Total revenues	229,607	374,714	444,915	817,770
Expenses
Production	81,776	66,953	171,274	173,809
Production taxes	4,382	7,840	8,896	15,647
Cost of sales	4,884	10,469	17,711	22,950
Midstream and marketing	7,724	13,254	15,831	29,254
Depreciation and depletion—oil and natural gas	94,298	97,267	200,405	212,452
Depreciation and amortization—other	12,508	15,411	25,855	30,933
Accretion of asset retirement obligations	1,111	1,065	2,191	6,811
Impairment	1,489,391	3,133	2,573,257	167,912
General and administrative	38,382	31,915	74,531	70,453
Loss (gain) on derivative contracts	33,004	85,292	(16,823)	127,783
(Gain) loss on sale of assets	(2,770)	36	(4,674)	17
Total expenses	1,764,690	332,635	3,068,454	858,021
(Loss) income from operations	(1,535,083)	42,079	(2,623,539)	(40,251)
Other (expense) income
Interest expense	(73,727)	(61,863)	(136,569)	(123,906)
Gain on extinguishment of debt	17,934	0	17,934	0
Other income, net	2,170	1,338	1,634	3,432
Total other expense	(53,623)	(60,525)	(117,001)	(120,474)
Loss before income taxes	(1,588,706)	(18,446)	(2,740,540)	(160,725)
Income tax expense (benefit)	25	(1,194)	65	(1,067)
Net loss	(1,588,731)	(17,252)	(2,740,605)	(159,658)
Less: net (loss) income attributable to noncontrolling interest	(220,249)	15,642	(337,170)	9,572
Net loss attributable to SandRidge Energy, Inc.	(1,368,482)	(32,894)	(2,403,435)	(169,230)
Preferred stock dividends	7,074	13,881	17,955	27,763
Loss applicable to SandRidge Energy, Inc. common stockholders	$ (1,375,556)	$ (46,775)	$ (2,421,390)	$ (196,993)
Loss per share
Basic (in dollars per share)	$ (2.78)	$ (0.10)	$ (4.98)	$ (0.41)
Diluted (in dollars per share)	$ (2.78)	$ (0.10)	$ (4.98)	$ (0.41)
Weighted average number of common shares outstanding
Basic	495,153	485,318	486,704	485,059
Diluted	495,153	485,318	486,704	485,059

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN EQUITY - 6 months ended Jun. 30, 2015 - USD ($) shares in Thousands, $ in Thousands	Total	Convertible Perpetual Preferred Stock	Common Stock	Additional Paid-In Capital	Treasury Stock	Accumulated Deficit	Non-controlling Interest
Beginning Balance (in shares) at Dec. 31, 2014	484,819		484,819
Beginning Balance at Dec. 31, 2014	$ 3,209,820	$ 6	$ 477	$ 5,201,524	$ (6,980)	$ (3,257,202)	$ 1,271,995
Beginning Balance (in shares) at Dec. 31, 2014		5,650
Increase (Decrease) in Stockholders' Equity
Distributions to noncontrolling interest owners	(84,690)						(84,690)
Purchase of treasury stock	(2,093)				(2,093)
Retirement of treasury stock	0			(2,093)	2,093
Stock distributions, net of purchases - retirement plans (in shares)			(198)
Stock distributions, net of purchases - retirement plans	64			(140)	204
Stock-based compensation	12,942			12,942
Cancellation of restricted stock awards, net of issuance (in shares)			(366)
Cancellation of restricted stock awards, net of issuance	0		$ 3	(3)
Common stock issued for debt exchange (in shares)			28,031
Common stock issued for debt exchange	31,396		$ 28	31,368
Net loss	(2,740,605)					(2,403,435)	(337,170)
Convertible perpetual preferred stock dividends (in shares)			5,672
Convertible perpetual preferred stock dividends	(11,262)		$ 6	6,687		(17,955)
Ending Balance at Jun. 30, 2015	$ 415,572	$ 6	$ 514	$ 5,250,285	$ (6,776)	$ (5,678,592)	$ 850,135
Ending Balance (in shares) at Jun. 30, 2015		5,650
Ending Balance (in shares) at Jun. 30, 2015	517,958		517,958

CONDENSED CONSOLIDATED STATEME6

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
CASH FLOWS FROM OPERATING ACTIVITIES
Net loss	$ (2,740,605)	$ (159,658)
Adjustments to reconcile net loss to net cash provided by operating activities
Depreciation, depletion and amortization	226,260	243,385
Accretion of asset retirement obligations	2,191	6,811
Impairment	2,573,257	167,912
Debt issuance costs amortization	4,636	4,703
Amortization of discount, net of premium, on long-term debt	285	258
Gain on extinguishment of debt	(17,934)	0
Write off of debt issuance costs	7,108	0
(Gain) loss on derivative contracts	(16,823)	127,783
Cash received (paid) on settlement of derivative contracts	211,323	(52,261)
(Gain) loss on sale of assets	(4,674)	17
Stock-based compensation	11,533	11,625
Other	680	(49)
Changes in operating assets and liabilities	61,757	(119,734)
Net cash provided by operating activities	318,994	230,792
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures for property, plant and equipment	(636,822)	(656,699)
Acquisition of assets	(3,475)	(16,553)
Proceeds from sale of assets	11,462	707,799
Net cash (used in) provided by investing activities	(628,835)	34,547
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from borrowings	2,190,000	0
Repayments of borrowings	(940,000)	0
Debt issuance costs	(39,129)	0
Proceeds from sale of royalty trust units	0	22,119
Noncontrolling interest distributions	(84,690)	(103,142)
Acquisition of ownership interest	0	(2,730)
Stock-based compensation excess tax benefit	0	2
Purchase of treasury stock	(2,714)	(5,602)
Dividends paid — preferred	(11,262)	(27,763)
Cash paid on settlement of financing derivative contracts	0	(44,128)
Net cash provided by (used in) financing activities	1,112,205	(161,244)
NET INCREASE IN CASH AND CASH EQUIVALENTS	802,364	104,095
CASH AND CASH EQUIVALENTS, beginning of year	181,253	814,663
CASH AND CASH EQUIVALENTS, end of period	983,617	918,758
Supplemental Disclosure of Cash Flow Information
Cash paid for interest, net of amounts capitalized	(177,245)	(120,339)
Cash paid for income taxes	(95)	(1,932)
Supplemental Disclosure of Noncash Investing and Financing Activities
Change in accrued capital expenditures	149,066	3,989
Equity issued for debt exchange	(31,396)	0
Preferred stock dividends paid in common stock	$ (6,693)	$ 0

Basis of Presentation

Basis of Presentation	6 Months Ended
	Jun. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	Basis of Presentation 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 region of the United States. The Company owns and operates additional interests in west Texas. The Company also operates businesses and infrastructure systems that are complementary to its primary exploration and production activities, including gas gathering and processing facilities, marketing operations, a saltwater gathering and disposal system, an electrical transmission system and a drilling and related oil field services business. Principles of Consolidation. The consolidated financial statements include the accounts of the Company and its wholly owned or majority owned subsidiaries and variable interest entities (“VIEs”) for which the Company is the primary beneficiary. Noncontrolling interest represents third-party ownership interests in the Company’s subsidiaries and consolidated VIEs and is included as a component of equity in the consolidated balance sheets and consolidated statement of changes in equity. All significant intercompany accounts and transactions have been eliminated in consolidation. Variable Interest Entities. An entity is referred to as a VIE if it possesses one of the following criteria: (i) it is thinly capitalized, (ii) the residual equity holders do not control the entity, (iii) the equity holders are shielded from economic losses, (iv) the equity holders do not participate fully in the entity’s residual economics, or (v) the entity was established with non-substantive voting interests. The Company consolidates a VIE when it has determined it is the primary beneficiary, which requires significant judgment. The primary beneficiary of a VIE is that variable interest holder possessing a controlling financial interest through (i) its power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and (ii) its obligation to absorb losses or its right to receive benefits from the VIE that could potentially be significant to the VIE. In order to determine whether the Company owns a variable interest in a VIE and the significance of the variable interest, the Company performs a qualitative analysis of the entity’s design, organizational structure, primary decision makers and related financial agreements. In addition to the VIEs that the Company consolidates, the Company also holds a variable interest in another VIE that is not consolidated as it was determined that the Company is not the entity’s primary beneficiary. The Company monitors both consolidated and unconsolidated VIEs to determine if any events have occurred that could cause the primary beneficiary to change. See Note 3 for discussion of the Company’s significant associated VIEs. Interim Financial Statements. The accompanying unaudited condensed consolidated financial statements as of December 31, 2014 have been derived from the audited financial statements contained in the Company’s 2014 Form 10-K. The unaudited interim condensed consolidated financial statements have been prepared in accordance with the accounting policies stated in the audited consolidated financial statements contained in the 2014 Form 10-K. Certain information and disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) have been condensed or omitted, although the Company believes that the disclosures contained herein are adequate to make the information presented not misleading. In the opinion of management, the accompanying financial statements include all adjustments, which consist of normal recurring adjustments, necessary to state fairly the information in the Company’s accompanying unaudited condensed consolidated financial statements. These unaudited condensed consolidated financial statements should be read in conjunction with the financial statements and notes thereto included in the 2014 Form 10-K. Significant Accounting Policies. For a description of the Company’s significant accounting policies, see Note 1 of the consolidated financial statements included in the 2014 Form 10-K. 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 accompanying unaudited condensed consolidated financial statements in conformity with GAAP 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; cash flow estimates used in the valuation of guarantees; impairment tests of long-lived assets; depreciation, depletion and amortization; asset retirement obligations; assignments of fair value and allocations of purchase price in connection with business combinations; 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. Recent Accounting Pronouncements. In April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-08, “Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity”, which amends the definition of a discontinued operations to elevate the threshold for a disposal transaction to qualify as a discontinued operation and requires entities to provide additional disclosures for disposal transactions that do not meet the discontinued operations criteria. The guidance is effective prospectively for all disposals (except disposals classified as held for sale before the adoption date) or components initially classified as held for sale in periods beginning on or after December 15, 2014, with early adoption permitted. The guidance was adopted January 1, 2015 and had no impact for the six -month period ended June 30, 2015 . Recent Accounting Pronouncements Not Yet Adopted. In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers”, which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance, including industry-specific guidance. The core principle requires that an entity recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. Certain of the provisions also amend or supersede existing guidance applicable to the recognition of a gain or loss on transfers of nonfinancial assets that are not an output of an entity’s ordinary activities, including sales of property, plant and equipment and real estate. The requirements of the guidance are effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period with an option of using either a full retrospective or a modified approach for adoption. The Company is currently evaluating the effect, if any, that the updated standard will have on its consolidated financial statements and related disclosures. In August 2014, the FASB issued ASU 2014-15, “Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern,” which provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued. An entity must provide certain disclosures if “conditions or events raise substantial doubt about the entity’s ability to continue as a going concern.” The guidance is effective for annual periods ending after December 15, 2016, and interim periods thereafter, with early adoption permitted. The Company is currently evaluating the effect the guidance will have on its related disclosures. In February 2015, the FASB issued ASU 2015-02, "Amendments to the Consolidation Analysis," which makes changes to both the variable interest model and the voting model, affecting all reporting entities involved with limited partnerships or similar entities, particularly industries such as the oil and gas, transportation and real estate sectors. In addition to reducing the number of consolidation models from four to two, the guidance simplifies and improves current guidance by placing more emphasis on risk of loss when determining a controlling financial interest and reducing the frequency of the application of related-party guidance when determining a controlling financial interest in a VIE. The requirements of the guidance are effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with early adoption permitted. The Company is currently evaluating the effect, if any, that the updated standard will have on its consolidated financial statements and related disclosures. In April 2015, the FASB issued ASU 2015-03, "Simplifying the Presentation of Debt Issuance Costs", which requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability, consistent with the presentation of a debt discount. The guidance is effective on a retrospective basis for annual periods beginning after December 15, 2015, including interim periods within that reporting period, with early adoption permitted. Adoption of the guidance will result in a decrease to the Company's assets and liabilities in the consolidated balance sheets, with no impact to the consolidated statements of operations.

Divestitures

Divestitures	6 Months Ended
	Jun. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
Divestitures	Divestitures Sale of Gulf of Mexico and Gulf Coast Properties On February 25, 2014 , the Company sold subsidiaries that owned the Company’s Gulf of Mexico and Gulf Coast oil and natural gas properties (the “Gulf Properties”) to Fieldwood Energy, LLC (“Fieldwood”) for approximately $702.6 million , net of working capital adjustments and post-closing adjustments, and the Fieldwood’s assumption of approximately $366.0 million of related asset retirement obligations. This transaction did not result in a significant alteration of the relationship between the Company’s capitalized costs and proved reserves and, accordingly, the Company recorded the proceeds as a reduction of its full cost pool with no gain or loss on the sale. See Note 14 for discussion of Fieldwood’s related party affiliation with the Company. In accordance with the terms of the sale, the Company agreed to guarantee on behalf of Fieldwood certain plugging and abandonment obligations associated with the Gulf Properties for a period of up to one year from the date of closing. The Company recorded a liability equal to the fair value of this guarantee, or $9.4 million , at the time the transaction closed. As of June 30, 2015 and December 31, 2014, the fair value of the guarantee was approximately $3.7 million and $5.1 million , respectively. See Note 4 for additional discussion of the determination of the guarantee fair value. The guarantee does not include a limit on the potential future payments for which the Company could be obligated; however, Fieldwood has agreed to indemnify the Company for any costs it may incur as a result of the guarantee and to use its best efforts to pay any amounts sought from the Company by the Bureau of Ocean Energy Management (“BOEM”) that may arise prior to the release of the guarantee. The Company has not incurred any costs as a result of this guarantee, which, as of February 25, 2015, it was permitted to terminate under the terms of the agreement with Fieldwood. The Company submitted a request for release of the guarantee to the BOEM on March 31, 2015 and expects to be released from the obligation during the third quarter of 2015. Additionally, Fieldwood maintained, for a period of up to one year from the closing date, restricted deposits held in escrow for plugging and abandonment obligations associated with the Gulf Properties. During the six -month period ended June 30, 2015 , the Company received its share of such deposits, net of any amounts payable to Fieldwood, or $12.0 million , in accordance with the terms of the sale. The following table presents revenues and expenses, including direct operating expenses, depletion, accretion of asset retirement obligations and general and administrative expenses, for the Gulf Properties included in the accompanying unaudited condensed consolidated statement of operations for the six -month period ended June 30, 2014 (in thousands): Six Months Ended June 30, 2014 (1) Revenues $ 90,920 Expenses $ 63,674 ____________________ (1) Includes revenues and expenses through February 25, 2014 , the date of the sale.

Variable Interest Entities

Variable Interest Entities	6 Months Ended
	Jun. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Variable Interest Entities	Variable Interest Entities The Company’s significant associated VIEs, including those for which the Company has determined it is the primary beneficiary and those for which it has determined it is not, are described below. Royalty Trusts SandRidge owns beneficial interests in the SandRidge Mississippian Trust I (the “Mississippian Trust I”), the SandRidge Permian Trust (the “Permian Trust”) and SandRidge Mississippian Trust II (the “Mississippian Trust II”) (each individually, a “Royalty Trust” and collectively, the “Royalty Trusts”). The Royalty Trusts are considered VIEs due to the lack of voting or similar decision-making rights of the Royalty Trusts’ equity holders regarding activities that have a significant effect on the economic success of the Royalty Trusts. The Company has determined it is the primary beneficiary of the Royalty Trusts as it has (a) the power to direct the activities that most significantly impact the economic performance of the Royalty Trusts through (i) its participation in the creation and structure of the Royalty Trusts, (ii) the manner in which it fulfilled its drilling obligations to the Royalty Trusts as discussed below and (iii) its operation of a majority of the oil and natural gas properties that are subject to the conveyed royalty interests and marketing of the associated production, and (b) the obligation to absorb losses and right to receive residual returns, through its variable interests in the Royalty Trusts, including ownership of common and/or subordinated units, that could potentially be significant to the Royalty Trusts. As a result, the Company consolidates the activities of the Royalty Trusts. The common units of the Royalty Trusts owned by third parties are reflected as noncontrolling interest in the consolidated financial statements. Common and subordinated units outstanding as of June 30, 2015 for each Royalty Trust are as follows: Mississippian Trust I Permian Trust Mississippian Trust II Total outstanding common units(1) 28,000,000 39,375,000 37,293,750 Total outstanding subordinated units(2) — 13,125,000 12,431,250 ____________________ (1) The Mississippian Trust I’s previously outstanding subordinated units, all of which were held by SandRidge, converted to common units in the third quarter of 2014. (2) All outstanding subordinated units are owned by SandRidge. The Company’s beneficial interests in the Royalty Trusts at June 30, 2015 and December 31, 2014 were as follows: June 30, December 31, Mississippian Trust I 26.9 % 26.9 % Permian Trust 25.0 % 25.0 % Mississippian Trust II 37.6 % 37.6 % Royalty Interests. Concurrent with the closing of the Mississippian Trust I and the Permian Trust initial public offerings in 2011 and the closing of the Mississippian Trust II initial public offering in 2012, the Company conveyed certain royalty interests to each Royalty Trust in exchange for (i) the net proceeds of the offering and (ii) common and subordinated units representing beneficial interests in the Royalty Trust. Royalty interests conveyed to the Royalty Trusts were in certain existing wells and wells to be drilled on oil and natural gas properties leased by the Company in defined areas of mutual interest. Pursuant to the agreements governing the Royalty Trusts, the Mississippian Trust I will terminate in 2030 and the Permian Trust and Mississippian Trust II will terminate in 2031. Upon termination, 50% of the royalty interests conveyed to the Royalty Trust will automatically revert to the Company, and the remaining 50% will be sold, with the proceeds distributed to the Royalty Trust unitholders. Drilling Obligations. The Company and one of its wholly owned subsidiaries entered into a development agreement with each Royalty Trust upon conveyance of the royalty interests that obligated the Company to drill, or cause to be drilled, a specified number of wells which are also subject to the royalty interests within respective areas of mutual interest by a specified date. One of the Company’s wholly owned subsidiaries also granted to each Royalty Trust a lien on the Company’s interests in the properties where the development wells were to be drilled in order to secure the estimated amount of drilling costs for the Royalty Trust’s interests in the wells. The total amount recoverable by each Royalty Trust under its respective lien was proportionately reduced as the Company drilled and completed the associated development wells. The Company fulfilled its drilling obligation to the Mississippian Trust I in the second quarter of 2013, to the Permian Trust in the fourth quarter of 2014 and to the Mississippian Trust II in the first quarter of 2015 and the related liens were automatically released. Distributions. The Royalty Trusts make quarterly cash distributions to unitholders based on calculated distributable income. Outstanding subordinated units, which constitute 25% of each Royalty Trust’s total outstanding units during the subordination period as described below, are entitled to receive pro rata distributions from the Royalty Trusts each quarter if and to the extent there is sufficient cash to provide a cash distribution on the common units that is no less than the applicable quarterly subordination threshold. If there is not sufficient cash to fund such a distribution on all common units, the distribution made with respect to the subordinated units is reduced or eliminated for such quarter in order to make a distribution, to the extent possible, of up to the subordination threshold amount on all common units, including common units held by the Company. As holder of the subordinated units, SandRidge is entitled to receive incentive distributions equal to 50% of the amount by which the cash available for distribution on all of the Royalty Trust units exceeds the applicable quarterly incentive threshold. Quarterly distributions declared and paid by the Royalty Trusts during the three and six -month periods ended June 30, 2015 and 2014 were as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015(1) 2014(2) 2015(1) 2014(2) Total distributions $ 47,296 $ 59,672 $ 97,499 $ 127,985 Distributions to third-party unitholders $ 40,975 $ 50,024 $ 84,690 $ 103,142 ____________________ (1) Subordination thresholds were not met for the Permian Trust and Mississippian Trust II’s distributions for the three and six -month periods ended June 30, 2015 , resulting in reduced distributions to the Company on its subordinated units for these periods. (2) Subordination thresholds were not met for the Mississippian Trust I’s distributions for the three and six -month periods ended June 30, 2014 and for the Mississippian Trust II’s distributions for the three-month period June 30, 2014 , resulting in reduced distributions to the Company on its subordinated units for these periods. See Note 18 for discussion of the Royalty Trusts’ distributions announced in July 2015. Following the end of the fourth full calendar quarter subsequent to the Company’s satisfaction of its drilling obligation (the “subordination period”), the subordinated units of each Royalty Trust automatically convert into common units on a one-for-one basis and the Company’s right to receive incentive distributions terminates. In the third quarter of 2014, the Mississippian Trust I’s subordinated units, all of which were held by SandRidge, converted to common units. Beginning with the distribution made in November 2014, all of the Mississippian Trust I’s common units share equally in its distributions. Similarly, as a result of the Company’s fulfillment of its drilling obligations to the Permian Trust and the Mississippian Trust II, the subordinated units of each of these Royalty Trusts will convert to common units on January 1, 2016 and April 1, 2016, respectively, and distributions made in respect of periods thereafter will be shared equally by the Royalty Trusts’ common units. The Company will continue to consolidate the activities of the Royalty Trusts as primary beneficiary subsequent to these conversions due to the Company’s original participation in the design of the Royalty Trusts and continued (a) power to direct the activities that most significantly impact the economic performance of the Royalty Trusts and (b) obligation to absorb losses and right to receive residual returns through its variable interests in the Royalty Trusts, including ownership of common units, that could potentially be significant to the Royalty Trusts. Loan Commitment. Pursuant to the trust agreements governing the Royalty Trusts, SandRidge has committed to loan funds to each Royalty Trust on an unsecured basis, with terms substantially the same as would be obtained in an arm’s length transaction between SandRidge and an unaffiliated party, if at any time the Royalty Trust’s cash is not sufficient to pay ordinary course administrative expenses as they become due. Any funds loaned may not be used to satisfy indebtedness of the Royalty Trust or to make distributions. There were no amounts outstanding under the loan commitments at June 30, 2015 or December 31, 2014 . Administrative Services. The Company is party to an administrative services agreement with each Royalty Trust, pursuant to which the Company provides certain administrative services to the Royalty Trust, including hedge management services to the Permian Trust and the Mississippian Trust II during the terms of the respective derivatives agreements. Derivative Agreements. The Company executed derivatives agreements with each Royalty Trust, pursuant to which the Company provides to the Royalty Trust the economic effects of certain of the Company’s derivative contracts. The tables below present the open oil and natural gas commodity derivative contracts at June 30, 2015 underlying the derivatives agreements with the Mississippian Trust I and Mississippian Trust II. The derivatives agreement with the Permian Trust contained commodity derivative contracts that covered volumes of oil production through March 31, 2015 and is no longer in effect. The combined volume in the tables below reflects the total volume of the Royalty Trusts’ open oil and natural gas commodity derivative contracts. Oil Price Swaps Underlying the Royalty Trust Derivatives Agreements Notional (MBbls) Weighted Average Fixed Price July 2015 - December 2015 374 $ 97.09 Natural Gas Collars Underlying the Royalty Trust Derivatives Agreements Notional (MMcf) Collar Range July 2015 - December 2015 509 $ 4.00 — $ 8.55 See Note 8 for further discussion of the derivatives agreement between the Company and each Royalty Trust. Assets and Liabilities. Each Royalty Trust’s assets can be used to settle only that Royalty Trust’s obligations and not other obligations of the Company or another Royalty Trust. The Royalty Trusts’ creditors have no contractual recourse to the general credit of the Company. Although the Royalty Trusts are included in the Company’s consolidated financial statements, the Company’s legal interest in the Royalty Trusts’ assets is limited to its ownership of the Royalty Trusts’ units. At June 30, 2015 and December 31, 2014 , $850.2 million and $1.3 billion , respectively, of noncontrolling interest in the accompanying unaudited condensed consolidated balance sheets was attributable to the Royalty Trusts. The Royalty Trusts’ assets and liabilities, after considering the effects of intercompany eliminations, included in the accompanying unaudited condensed consolidated balance sheets at June 30, 2015 and December 31, 2014 consisted of the following (in thousands): June 30, December 31, Cash and cash equivalents(1) $ 9,062 $ 9,387 Accounts receivable, net 8,455 17,660 Derivative contracts — 6,589 Total current assets 17,517 33,636 Investment in royalty interests(2) 1,325,942 1,325,942 Less: accumulated depletion and impairment(3) (808,890 ) (284,094 ) 517,052 1,041,848 Total assets $ 534,569 $ 1,075,484 Accounts payable and accrued expenses $ 185 $ 2,852 Total liabilities $ 185 $ 2,852 ____________________ (1) Includes $3.0 million held by the trustee at June 30, 2015 and December 31, 2014 as reserves for future general and administrative expenses. (2) Investment in royalty interests is included in oil and natural gas properties in the accompanying unaudited condensed consolidated balance sheets. (3) Includes cumulative full cost ceiling limitation impairment of $547.5 million and $42.3 million at June 30, 2015 and December 31, 2014 , respectively. See Note 10 for discussion of the Company’s legal proceedings to which the Mississippian Trust I and Mississippian Trust II are also parties. Sales of Common Units. During the six -month period ended June 30, 2014 , the Company sold Permian Trust common units it owned in a transaction exempt from registration pursuant to Rule 144 under the Securities Act for proceeds of approximately $22.1 million . The sale was accounted for as an equity transaction with no gain or loss recognized. The Company continues to be the primary beneficiary of the Permian Trust after consideration of this transaction and continues to consolidate the activities of the Permian Trust as well as the activities of the Mississippian Trust I and Mississippian Trust II. Grey Ranch Plant, L.P. The Company owned a 50% interest in Grey Ranch Plant, L.P. (“GRLP”), which represented a variable interest, prior to one of the Company’s wholly owned subsidiaries acquiring the remaining 50% ownership interest of GRLP from a third party during the first quarter of 2014. The third-party ownership interest in GRLP for the six -month period ended June 30, 2014 is reflected in loss attributable to noncontrolling interest owners in the accompanying unaudited condensed consolidated statement of operations. Because the Company was the primary beneficiary and consolidated GRLP, the acquisition of additional ownership interest was recorded as an equity transaction with no gain or loss recognized. Additionally, as a wholly owned subsidiary of the Company, GRLP is no longer considered a VIE for reporting purposes. Grey Ranch Plant Genpar, LLC The Company owned a 50% interest in Grey Ranch Plant Genpar, LLC (“Genpar”), the managing partner and 1% owner of GRLP, prior to one of the Company’s wholly owned subsidiaries acquiring the remaining 50% ownership interest of Genpar from a third party in the first quarter of 2014. Because the Company was the primary beneficiary and consolidated Genpar, the acquisition of additional ownership interest was recorded as an equity transaction with no gain or loss recognized. Additionally, as a wholly owned subsidiary of the Company, Genpar is no longer considered a VIE for reporting purposes. Piñon Gathering Company, LLC The Company has a gas gathering and operations and maintenance agreement with Piñon Gathering Company, LLC (“PGC”) through June 30, 2029 . Under the gas gathering agreement, the Company is required to compensate PGC for any throughput shortfalls below a required minimum volume. By guaranteeing a minimum throughput, the Company absorbs the risk that lower than projected volumes will be gathered by the gathering system. Therefore, PGC is a VIE. Other than as required under the gas gathering and operations and maintenance agreements, the Company has not provided any support to PGC. While the Company operates the assets of PGC as directed under the operations and management agreement, the member and managers of PGC have the authority to directly control PGC and make substantive decisions regarding PGC’s activities including terminating the Company as operator without cause. Because the Company does not have the ability to control the activities of PGC that most significantly impact PGC’s economic performance, the Company is not the primary beneficiary of PGC and does not consolidate the results of PGC’s activities into its financial statements. Amounts due from and due to PGC as of June 30, 2015 and December 31, 2014 included in the accompanying unaudited condensed consolidated balance sheets are as follows (in thousands): June 30, December 31, Accounts receivable due from PGC $ 1,104 $ 1,141 Accounts payable due to PGC $ 4,011 $ 4,163

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The Company measures and reports certain assets and liabilities on a fair value basis and has classified and disclosed its fair value measurements using the following levels of the fair value hierarchy: Level 1 Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. Level 2 Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability. Level 3 Measurement based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable for objective sources (i.e., supported by little or no market activity). Assets and liabilities that are measured at fair value are classified based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The determination of the fair values, stated below, considers the market for the Company’s financial assets and liabilities, the associated credit risk and other factors. The Company considers active markets as those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis. The Company has assets and liabilities classified as Level 1, Level 2 and Level 3 as of June 30, 2015 and December 31, 2014 , as described below. Level 1 Fair Value Measurements Investments. The fair value of investments, consisting of assets attributable to the Company’s non-qualified deferred compensation plan, is based on quoted market prices. Investments are included in other assets in the accompanying unaudited condensed consolidated balance sheets. Level 2 Fair Value Measurements Derivative contracts. The fair values of the Company’s oil and natural gas fixed price swaps and oil and natural gas collars are based upon inputs that are either readily available in the public market, such as oil and natural gas futures prices, volatility factors and discount rates, or can be corroborated from active markets. Fair value is determined through the use of a discounted cash flow model or option pricing model using the applicable inputs, discussed above. The Company applies a weighted average credit default risk rating factor for its counterparties or gives effect to its credit default risk rating, as applicable, in determining the fair value of these derivative contracts. Credit default risk ratings are based on current published credit default swap rates. Level 3 Fair Value Measurements Guarantee. As discussed in Note 2 , the Company has guaranteed on Fieldwood’s behalf certain plugging and abandonment obligations associated with the Gulf Properties. The fair value of this guarantee is based on the present value of estimated future payments for plugging and abandonment obligations associated with the Gulf Properties, adjusted for the cumulative probability of Fieldwood’s default prior to the approximate date on which the Company expects to be released by the BOEM from its obligation under the guarantee ( 3.59% and 3.71% at June 30, 2015 and December 31, 2014 , respectively). The discount and probability of default rates are based upon inputs that are readily available in the public market, such as historical option adjusted spreads of the Company’s senior notes, which are publicly traded, and historical default rates of publicly traded companies with credit ratings similar to Fieldwood. The significant unobservable input used in the fair value measurement of the guarantee is the estimate of future payments for plugging and abandonment, which was developed based upon third-party quotes and current actual costs. Significant increases (decreases) in the estimate of these payments could result in a significantly higher (lower) fair value measurement. The significant unobservable input used in the fair value measurement of the Company’s financial guarantee liability at June 30, 2015 and December 31, 2014 is included in the table below (in thousands). Unobservable Input Estimated future payments for plugging and abandonment $ 372,034 Derivative contracts. The fair values of the Company’s natural gas basis swaps are based upon quotes obtained from counterparties to the derivative contracts. These values were reviewed internally for reasonableness through the use of a discounted cash flow model using non-exchange traded regional pricing information. Additionally, the Company applied a weighted average credit default risk rating factor for its counterparties or gave effect to its credit risk, as applicable, in determining the fair value of these derivative contracts. The significant unobservable input used in the fair value measurement of the Company’s natural gas basis swaps is the estimate of future natural gas basis differentials. Significant increases (decreases) in natural gas basis differentials could result in a significantly higher (lower) fair value measurement. The significant unobservable inputs and the range and weighted average of these inputs used in the fair value measurements of the Company’s natural gas basis swaps at June 30, 2015 and December 31, 2014 are included in the table below. Unobservable Input Range Weighted Average Fair Value (Price per Mcf) (In thousands) June 30, 2015 Natural gas basis differential forward curve $ (0.12 ) – $ (0.45 ) $ (0.27 ) $ (2,207 ) December 31, 2014 Natural gas basis differential forward curve $ (0.03 ) – $ (0.38 ) $ (0.29 ) $ 350 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): June 30, 2015 Fair Value Measurements Netting(1) Assets/Liabilities at Fair Value Level 1 Level 2 Level 3 Assets Commodity derivative contracts $ — $ 146,124 $ — $ (2,079 ) $ 144,045 Investments 10,882 — — — 10,882 $ 10,882 $ 146,124 $ — $ (2,079 ) $ 154,927 Liabilities Guarantee $ — $ — $ 3,736 $ — $ 3,736 Commodity derivative contracts — — 2,207 (2,079 ) 128 $ — $ — $ 5,943 $ (2,079 ) $ 3,864 December 31, 2014 Fair Value Measurements Netting(1) Assets/Liabilities at Fair Value Level 1 Level 2 Level 3 Assets Commodity derivative contracts $ — $ 338,067 $ 350 $ — $ 338,417 Investments 11,106 — — — 11,106 $ 11,106 $ 338,067 $ 350 $ — $ 349,523 Liabilities Guarantee $ — $ — $ 5,104 $ — $ 5,104 $ — $ — $ 5,104 $ — $ 5,104 ____________________ (1) Represents the effect of netting assets and liabilities for counterparties with which the right of offset exists. The table below sets forth a reconciliation of the Company’s Level 3 fair value measurements for the guarantee during the three and six -month periods ended June 30, 2015 and 2014 (in thousands): Three Months Ended June 30, Six Months Ended June 30, Level 3 Fair Value Measurements - Guarantee 2015 2014 2015 2014 Beginning balance $ 4,791 $ 9,480 $ 5,104 $ — Issuances(1) — — — 9,446 (Gain) loss on guarantee (1,055 ) 2,548 (1,368 ) 2,582 Ending balance $ 3,736 $ 12,028 $ 3,736 $ 12,028 ____________________ (1) Represents the fair value of the guarantee of certain plugging and abandonment obligations on behalf of Fieldwood as of February 25, 2014, the closing date for the sale of the Gulf Properties, for the six -month period ended June 30, 2014 . The fair value of the guarantee is determined quarterly with changes in fair value recorded as an adjustment to the full cost pool. See Note 2 for discussion of the sale of the Gulf Properties. The fair value of the guarantee as of June 30, 2015 and December 31, 2014 is included in other current liabilities in the accompanying unaudited condensed consolidated balance sheets. The table below sets forth a reconciliation of the Company’s Level 3 fair value measurements for commodity derivative contracts during the three and six -month periods ended June 30, 2015 (in thousands): Level 3 Fair Value Measurements - Commodity Derivative Contracts Three Months Ended June 30, 2015 Six Months Ended June 30, 2015 Beginning balance $ 1,332 $ 350 Purchases — (1,847 ) Loss on derivative contracts (3,539 ) (710 ) Ending balance $ (2,207 ) $ (2,207 ) Losses due to changes in fair value of the Company’s Level 3 commodity derivative contracts have been included in loss (gain) on derivative contracts in the accompanying unaudited condensed consolidated statements of operations. There were no outstanding Level 3 commodity derivative contracts at June 30, 2014 . See Note 8 for further discussion of the Company’s derivative contracts. 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 three and six -month periods ended June 30, 2015 and 2014 , the Company did not have any transfers between Level 1, Level 2 or Level 3 fair value measurements. Fair Value of Financial Instruments The Company measures the fair value of its 8.75% Senior Secured Notes due 2020 (“Senior Secured Notes”) and its 8.75% Senior Notes due 2020, 7.25% Senior Notes due 2021, 8.125% Senior Notes due 2022, and 7.5% Senior Notes due 2023 (collectively, “Senior Unsecured Notes”), using pricing that is readily available in the public market. The Company classifies these inputs as Level 2 in the fair value hierarchy. The estimated fair values and carrying values of the Company’s senior notes at June 30, 2015 and December 31, 2014 were as follows (in thousands): June 30, 2015 December 31, 2014 Fair Value Carrying Value Fair Value Carrying Value 8.75% Senior Secured Notes due 2020 $ 1,134,375 $ 1,250,000 $ — $ — Senior Unsecured Notes 8.75% Senior Notes due 2020(1) $ 243,000 $ 445,758 $ 303,750 $ 445,402 7.5% Senior Notes due 2021(2) $ 514,063 $ 1,149,175 $ 752,000 $ 1,178,486 8.125% Senior Notes due 2022 $ 320,625 $ 729,000 $ 472,500 $ 750,000 7.5% Senior Notes due 2023(3) $ 348,728 $ 821,706 $ 519,750 $ 821,548 ____________________ (1) Carrying value is net of $4,242 and $4,598 discount at June 30, 2015 and December 31, 2014 , respectively. (2) Carrying value includes a premium of $3,175 and $3,486 at June 30, 2015 and December 31, 2014 , respectively. (3) Carrying value is net of $3,294 and $3,452 discount at June 30, 2015 and December 31, 2014 , respectively. See Note 7 for discussion of the Company’s long-term debt.

Property, Plant and Equipment

Property, Plant and Equipment	6 Months Ended
	Jun. 30, 2015
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment consists of the following (in thousands): June 30, December 31, Oil and natural gas properties Proved(1) $ 12,199,049 $ 11,707,147 Unproved 261,657 290,596 Total oil and natural gas properties 12,460,706 11,997,743 Less accumulated depreciation, depletion and impairment (9,131,153 ) (6,359,149 ) Net oil and natural gas properties capitalized costs 3,329,553 5,638,594 Land 14,648 16,300 Non-oil and natural gas equipment(2) 482,923 602,392 Buildings and structures(3) 271,367 263,191 Total 768,938 881,883 Less accumulated depreciation and amortization (212,090 ) (305,420 ) Other property, plant and equipment, net 556,848 576,463 Total property, plant and equipment, net $ 3,886,401 $ 6,215,057 ____________________ (1) Includes cumulative capitalized interest of approximately $45.6 million and $38.1 million at June 30, 2015 and December 31, 2014 , respectively. (2) Includes cumulative capitalized interest of approximately $4.3 million at both June 30, 2015 and December 31, 2014 . (3) Includes cumulative capitalized interest of approximately $19.2 million and $17.1 million at June 30, 2015 and December 31, 2014 , respectively. Accumulated depreciation, depletion and impairment on oil and natural gas properties includes cumulative full cost ceiling limitation impairment of $6.3 billion and $3.7 billion at June 30, 2015 and December 31, 2014 , respectively. The Company reduced the net carrying value of its oil and natural gas properties by $1.5 billion and $2.6 billion during the three and six -month periods ended June 30, 2015 , respectively, and by $164.8 million during the six -month period ended June 30, 2014 , as a result of its quarterly full cost ceiling analyses. Drilling Assets. During the six-month period ended June 30, 2015 , the Company decided to discontinue all remaining drilling and oilfield services operations in the Permian region and during the second quarter of 2015 classified the related assets, having a net book value of approximately $20.0 million , as held for sale, which is included in other current assets in the accompanying unaudited condensed consolidated balance sheet at June 30, 2015 . The Company intends to dispose of the assets during the third quarter of 2015. Drilling Carry Commitments During the six -month period ended June 30, 2014 , the Company was party to an agreement with a co-working interest party, Repsol E&P USA, Inc.’s (“Repsol”), which contained a carry commitment to fund a portion of the Company’s future drilling, completing and equipping costs within areas of mutual interest. The Company recorded approximately $175.4 million for Repsol’s carry during the six -month period ended June 30, 2014 , which reduced the Company’s capital expenditures for the period. Repsol fully funded its carry commitment in the third quarter of 2014 . Under the original agreement, the carry commitment could have been reduced if a certain number of wells were not drilled within the area of mutual interest during a twelve-month period and the Company failed to drill such wells following a proposal by Repsol to drill the wells. During 2013, the Company temporarily reduced its rate of drilling activity. As a result, the Company drilled less than the targeted number of wells for such twelve-month period, which resulted in Repsol having a right to propose additional wells. In the second quarter of 2014, the Company and Repsol amended the agreement to eliminate Repsol’s right to propose such additional wells in exchange for a commitment by the Company to drill 484 net wells in the area of mutual interest between January 1, 2014 and May 31, 2015, subject to delays due to factors beyond the Company’s control. Under the terms of the amended agreement, the Company agreed to carry Repsol’s future drilling and completion costs in the amount of approximately $1.0 million for each well of the 484 commitment that it did not drill, up to a maximum of $75.0 million in carry costs. As of May 31, 2015, the Company had drilled 453 net wells under this arrangement. As a result, the Company anticipates that it will carry a portion of Repsol’s drilling and completion costs totaling up to approximately $31.0 million for wells drilled in the future in the area of mutual interest. Other than the above, the Company has no carry or drilling obligations to Repsol.

Other Assets

Other Assets	6 Months Ended
	Jun. 30, 2015
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Other Assets	Other Assets Other assets consist of the following (in thousands): June 30, December 31, Debt issuance costs, net of amortization $ 83,065 $ 56,445 Deferred tax asset 52,763 95,843 Investments 10,882 11,106 Other 632 1,853 Total other assets $ 147,342 $ 165,247

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt consists of the following (in thousands): June 30, December 31, Senior credit facility $ — $ — 8.75% Senior Secured Notes due 2020 1,250,000 — Senior Unsecured Notes 8.75% Senior Notes due 2020, net of $4,242 and $4,598 discount, respectively 445,758 445,402 7.5% Senior Notes due 2021, including premium of $3,175 and $3,486, respectively 1,149,175 1,178,486 8.125% Senior Notes due 2022 729,000 750,000 7.5% Senior Notes due 2023, net of $3,294 and $3,452 discount, respectively 821,706 821,548 Total debt 4,395,639 3,195,436 Less: current maturities of long-term debt — — Long-term debt $ 4,395,639 $ 3,195,436 Senior Credit Facility The senior secured revolving credit facility (the “senior credit facility”), as amended, is available to be drawn on subject to limitations based on its terms and certain financial covenants, as described below. Prior to its amendment and restatement on June 10, 2015, the senior credit facility contained certain financial covenants, including maintenance of agreed upon levels for (a) ratio of total debt secured by assets of the Company and certain of its subsidiaries to EBITDA, which was not permitted to exceed 2.25 :1.00 at each quarter end, calculated using the last four completed fiscal quarters, (b) ratio of EBITDA to interest expense, which was required to be at least 2.00 :1.00 at March 31, 2015 and June 30, 2015, 1.75 :1.00 at September 30, 2015, 1.50 :1.00 at each quarter end from December 31, 2015 to September 30, 2016, and 2.00 :1.00 at December 31, 2016 and thereafter, calculated using the last four completed fiscal quarters, and (c) ratio of current assets to current liabilities, which was required to be at least 1.00 :1.00 at each quarter end. A February 2015 amendment temporarily suspended until June 30, 2016 the financial covenant requiring maintenance of certain levels for the ratio of total net debt to EBITDA. For periods after such time, the ratio of total net debt to EBITDA could not exceed 6.25 :1.00 at June 30, 2016, 6.00 :1.00 at September 30, 2016 and December 31, 2016, 5.50 :1.00 at March 31, 2017 and June 30, 2017, 5.00 :1.00 at September 30, 2017 and December 31, 2017 and 4.50 :1.00 at March 31, 2018 and thereafter, calculated using annualized EBITDA for the fiscal quarter ended June 30, 2016 and the two subsequent fiscal quarters and otherwise calculated using the last four completed fiscal quarters. The senior credit facility was amended and restated on June 10, 2015 (the “June Amendment”). In connection with the June Amendment, the then-existing financial covenants were replaced. As of then and as of June 30, 2015, the senior credit facility contains financial covenants, including maintenance of agreed upon levels for the (a) ratio of total secured debt under the senior credit facility to EBITDA, which may not exceed 2.00 :1.00 at each quarter end and (b) ratio of current assets to current liabilities, which must be at least 1.0 :1.0 at each quarter end. For the purpose of the current ratio calculation, any amounts available to be drawn under the senior credit facility are included in current assets, and unrealized assets and liabilities resulting from mark-to-market adjustments on the Company’s derivative contracts are disregarded. The senior credit facility matures on the earlier of March 2, 2020 and 91 days prior to the earliest date of any maturity under or mandatory offer to repurchase the Company’s currently outstanding notes. Prior and subsequent to the June Amendment, the senior credit facility also contains various covenants that limit the ability of the Company and certain of its subsidiaries to: grant certain liens; make certain loans and investments; make distributions; redeem stock; redeem or prepay debt; merge or consolidate with or into a third party; or engage in certain asset dispositions, including a sale of all or substantially all of the Company’s assets. Additionally, the senior credit facility limits the ability of the Company and certain of its subsidiaries to incur additional indebtedness with certain exceptions. As of and during the three and six -month periods ended June 30, 2015 , the Company was in compliance with all applicable financial covenants under the senior credit facility, including those in effect prior to the June Amendment. The obligations under the senior credit facility are guaranteed by certain Company subsidiaries and are secured by first priority liens on all shares of capital stock of certain of the Company’s material present and future subsidiaries, all of the Company’s intercompany debt, and certain of the Company’s other assets, including proved oil, natural gas and NGL reserves representing at least 80.0% of the discounted present value (as defined in the senior credit facility) of proved oil, natural gas and NGL reserves of the Company. At the Company’s election, interest under the senior credit facility, as amended, is determined by reference to (a) the ICE Benchmark Administration Limited LIBOR (“LIBOR”) plus an applicable margin between 1.750% and 2.750% per annum or (b) the “base rate,” which is the highest of (i) the federal funds rate plus 0.5% , (ii) the prime rate published by Royal Bank of Canada under the senior credit facility or (iii) the one-month Eurodollar rate (as defined in the senior credit facility) plus 1.00% per annum, plus, in each case under scenario (b), an applicable margin between 0.750% and 1.750% per annum. Interest is payable quarterly for base rate loans and at the applicable maturity date for LIBOR loans, except that if the interest period for a LIBOR loan is six months or longer, interest is paid at the end of each three-month period. Quarterly, the Company pays commitment fees assessed at an annual rate of 0.5% on any available portion of the senior credit facility. Borrowings and letter of credit obligations under the senior credit facility may not exceed the lower of the committed amount, which is currently $1.0 billion , or the borrowing base, which is currently $500.0 million and is subject to periodic redeterminations. Prior to the June Amendment, the borrowing base was $900.0 million . This reduction in borrowing base resulted in the write off of approximately $4.9 million of capitalized debt issuance costs. The next scheduled borrowing base redetermination is expected to take place in October 2015. With respect to each redetermination, the administrative agent and the lenders under the senior credit facility consider several factors, including the Company’s proved reserves and projected cash requirements, and make assumptions regarding, among other things, oil and natural gas prices and production. Because the value of the Company’s proved reserves is a key factor in determining the amount of the borrowing base, changing commodity prices and the Company’s success in developing reserves may affect the borrowing base. The Company at times incurs additional costs related to the senior credit facility as a result of amendments to the credit agreement and changes to the borrowing base. Additionally, the amended senior credit agreement permits the Company and certain of its subsidiaries to incur additional indebtedness in an aggregate principal amount not to exceed $1.75 billion , which may be secured solely by collateral securing the senior credit facility on a junior lien basis. Any junior lien debt shall be subject to the terms and conditions set forth in an intercreditor agreement and shall mature no earlier than January 21, 2020. The borrowing base under the senior credit facility will be reduced by $0.25 for every $1.00 of junior debt incurred above $1.50 billion . The Company did not draw on the senior credit facility during 2014. The senior credit facility was undrawn at June 30, 2015 and had $26.8 million in outstanding letters of credit, which reduce the availability under the senior credit facility on a dollar-for-dollar basis. At June 30, 2015 , the Company had incurred $1.25 billion in junior lien debt subject to an intercreditor agreement as a result of the issuance of Senior Secured Notes in June 2015 as described further below. Senior Secured Notes Concurrent with the amendment and restatement of the Company’s senior credit facility discussed above, in June 2015 the Company issued $1.25 billion of Senior Secured Notes. Net proceeds from the issuance were approximately $1.21 billion after deducting offering expenses, a portion of which was used to repay amounts outstanding at that time under the Company’s senior credit facility. The Senior Secured Notes were issued to qualified institutional buyers eligible under Rule 144A of the Securities Act and to persons outside the United States under Regulation S of the Securities Act. The Company’s Senior Secured Notes bear interest at a fixed rate of 8.75% per annum, payable semi-annually, with the principal due upon maturity. The Senior Secured Notes are redeemable, in whole or in part, prior to their maturity at specified redemption prices and are jointly and severally guaranteed unconditionally, in full, on a second-priority secured basis by certain of the Company’s wholly owned subsidiaries. See Note 17 for condensed financial information of the subsidiary guarantors. Pursuant to the indenture, the Senior Secured Notes will mature on June 1, 2020; provided, however, that if on October 15, 2019, the aggregate outstanding principal amount of the unsecured 8.75% Senior Notes due 2020 exceeds $100.0 million , the Senior Secured Notes will mature on October 16, 2019. The Senior Secured Notes are secured by second-priority liens on all of the Company’s and certain of the Company’s wholly owned subsidiaries’ assets that secure the senior credit facility on a first-priority basis; provided, however, the security interest in those assets that secure the Senior Secured Notes and the guarantees will be contractually subordinated to liens thereon that secure the credit facility and certain other permitted indebtedness. Consequently, the Senior Secured Notes and the guarantees will be effectively subordinated to the credit facility and such other indebtedness to the extent of the value of such assets. Debt issuance costs of $37.0 million incurred in connection with the offering of the Senior Secured Notes outstanding at June 30, 2015 are included in other assets in the accompanying unaudited condensed consolidated balance sheets and are being amortized to interest expense over the term of Senior Secured Notes. Indenture. The indenture governing the Senior Secured Notes contains covenants that restrict the Company’s ability to take a variety of actions, including limitations on the payment of dividends, incurrence of indebtedness, create liens, enter into consolidations or mergers, purchase or redeem stock or subordinated or unsecured indebtedness, certain dispositions and transfers of assets, transactions with related parties, make investments and refinance certain indebtedness. As of and during the three-month period ended June 30, 2015 , the Company was in compliance with all of the covenants contained in the indenture governing its outstanding Senior Secured Notes. Because the Senior Secured Notes were not issued until June 2015, the covenants contained therein were not applicable during the three-month period ended March 31, 2015. Senior Unsecured Notes The Company’s Senior Unsecured Notes bear interest at a fixed rate per annum, payable semi-annually, with the principal due upon maturity. Certain of the Senior Unsecured Notes were issued at a discount or a premium. The discount or premium is amortized to interest expense over the term of the respective series of Senior Unsecured Notes. The Senior Unsecured Notes are redeemable, in whole or in part, prior to their maturity at specified redemption prices and are jointly and severally guaranteed unconditionally, in full, on an unsecured basis by certain of the Company’s wholly owned subsidiaries. See Note 17 for condensed financial information of the subsidiary guarantors. Debt issuance costs of $69.0 million incurred in connection with the offerings and subsequent registered exchange offers of the Senior Unsecured Notes outstanding at June 30, 2015 are included in other assets in the accompanying unaudited condensed consolidated balance sheets and are being amortized to interest expense over the term of the respective series of Senior Unsecured Notes. Redemption of Senior Unsecured Notes. During the three-month period ended June 30, 2015 , the Company issued to a holder of its 7.5% Senior Notes due 2021 and 8.125% Senior Notes due 2022, approximately 28.0 million shares of the Company’s common stock in exchange for an aggregate $50.0 million principal amount of the notes ( $29.0 million of 7.5% Senior Notes due 2021 and $21.0 million of 8.125% Senior Notes due 2022) and as payment for the interest accrued thereon since the last interest payment date. The exchange resulted in a gain on extinguishment of $17.9 million , which is included in income on the unaudited condensed consolidated statements of operations for the three and six -month periods ended June 30, 2015 . Indentures. Each of the indentures governing the Company’s Senior Unsecured Notes contains covenants that restrict the Company’s ability to take a variety of actions, including limitations on the incurrence of indebtedness, payment of dividends, investments, asset sales, certain asset purchases, transactions with related parties and consolidations or mergers. As of and during the three and six -month periods ended June 30, 2015 , the Company was in compliance with all of the covenants contained in the indentures governing its outstanding Senior Unsecured Notes.

Derivatives

Derivatives	6 Months Ended
	Jun. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives The Company has not designated any of its derivative contracts as hedges for accounting purposes. The Company records all derivative contracts at fair value. Changes in derivative contract fair values are recognized in earnings. Cash settlements and valuation gains and losses are included in loss (gain) on derivative contracts in the unaudited condensed consolidated statements of operations. Commodity derivative contracts are settled on a monthly or quarterly basis. Derivative assets and liabilities arising from the Company’s derivative contracts with the same counterparty that provide for net settlement are reported on a net basis in the consolidated balance sheets. 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. These derivative contracts allow the Company to limit its exposure to commodity price volatility on a portion of its forecasted oil and natural gas sales. None of the Company’s 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. At June 30, 2015 , the Company’s commodity derivative contracts consisted of fixed price swaps, basis swaps and collars, which are described below: Fixed price swaps The Company receives a fixed price for the contract and pays a floating market price to the counterparty over a specified period for a contracted volume. Basis swaps The Company receives a payment from the counterparty if the settled price differential is greater than the stated terms of the contract and pays the counterparty if the settled price differential is less than the stated terms of the contract, which guarantees the Company a price differential for oil or natural gas from a specified delivery point. Collars Two-way collars contain a fixed floor price (put) and a fixed ceiling price (call). If the market price exceeds the call strike price or falls below the put strike price, the Company receives the fixed price and pays the market price. If the market price is between the call and the put strike price, no payments are due from either party. Three-way collars have two fixed floor prices (a purchased put and a sold put) and a fixed ceiling price (call). The purchased put establishes a minimum price unless the market price falls below the sold put, at which point the minimum price would be New York Mercantile Exchange (“NYMEX”) plus the difference between the purchased put and the sold put strike price. The call establishes a maximum price (ceiling) the Company will receive for the volumes under the contract. If the market price is between the ceiling price and purchased put, no payments are due from either party. Derivatives Agreements with Royalty Trusts. The Company is party to derivatives agreements with the Mississippian Trust I, Permian Trust and Mississippian Trust II to provide each Royalty Trust with the economic effect of certain oil and natural gas derivative contracts entered into by the Company with third parties. The underlying commodity derivative contracts cover volumes of oil and natural gas production through December 31, 2015 for the Mississippian Trust I and Mississippian Trust II. Under these arrangements, the Company pays the Royalty Trusts amounts it receives from its counterparties in accordance with the underlying contracts, and the Royalty Trusts pay the Company any amounts that the Company is required to pay its counterparties under such contracts. The derivatives agreement with the Permian Trust contained commodity derivative contracts that covered volumes of oil production through March 31, 2015 and is no longer in effect. In accordance with the terms of the respective derivatives agreements, the Company novated certain of the derivative contracts underlying the derivatives agreements to each of the Permian Trust and the Mississippian Trust II. As a party to these contracts, the Permian Trust and the Mississippian Trust II received payment directly from the counterparty and paid any amounts owed directly to the counterparty. To secure its obligations under the respective derivative contracts novated to it, each of the Permian Trust and the Mississippian Trust II granted the counterparties liens on the royalty interests held by each respective Royalty Trust. As of June 30, 2015 , there were no novated derivative contracts outstanding under the derivatives agreements. All contracts underlying the derivatives agreements with the Royalty Trusts have been included in the Company’s consolidated derivative disclosures. See Note 3 for the Royalty Trusts’ open derivative contracts. Fair Value of Derivatives. The following table presents the fair value of the Company’s derivative contracts as of June 30, 2015 and December 31, 2014 on a gross basis without regard to same-counterparty netting (in thousands): Type of Contract Balance Sheet Classification June 30, December 31, Derivative assets Oil price swaps Derivative contracts-current $ 70,528 $ 204,072 Natural gas price swaps Derivative contracts-current 4,757 29,648 Natural gas basis swaps Derivative contracts-current — 350 Oil collars - three way Derivative contracts-current 46,825 56,289 Natural gas collars Derivative contracts-current 562 1,055 Oil price swaps Derivative contracts-noncurrent 18,867 36,288 Oil collars - three way Derivative contracts-noncurrent 4,585 10,715 Derivative liabilities Natural gas basis swaps Derivative contracts-current (2,199 ) — Natural gas basis swaps Derivative contracts-noncurrent (8 ) — Total net derivative contracts $ 143,917 $ 338,417 See Note 4 for additional discussion of the fair value measurement of the Company’s derivative contracts. Master Netting Agreements and the Right of Offset. The Company has master netting agreements with all of its derivative counterparties and has presented its derivative assets and liabilities with the same counterparty on a net basis in the consolidated balance sheets. As a result of the netting provisions, the Company's maximum amount of loss under derivative transactions due to credit risk is limited to the net amounts due from its counterparties. As of June 30, 2015 , the counterparties to the Company’s open derivative contracts consisted of nine financial institutions, five of which are also lenders under the Company’s senior credit facility. The Company is not required to post additional collateral under its derivative contracts as the majority of the counterparties to the Company’s derivative contracts share in the collateral supporting the Company’s senior credit facility. To secure their obligations under the derivative contracts novated by the Company, the Permian Trust and the Mississippian Trust II each gave the counterparties to such contracts a lien on its royalty interests. As of June 30, 2015, the terms of all such novated contracts had expired. The following tables summarize (i) the Company's derivative contracts on a gross basis, (ii) the effects of netting assets and liabilities for which the right of offset exists based on master netting arrangements and (iii) for the Company’s net derivative liability positions, the applicable portion of shared collateral under the senior credit facility (in thousands): June 30, 2015 Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount Assets Derivative contracts - current $ 122,672 $ (2,097 ) $ 120,575 $ — $ 120,575 Derivative contracts - noncurrent 23,452 18 23,470 — 23,470 Total $ 146,124 $ (2,079 ) $ 144,045 $ — $ 144,045 Liabilities Derivative contracts - current $ 2,199 $ (2,097 ) $ 102 $ (102 ) $ — Derivative contracts - noncurrent 8 18 26 (26 ) — Total $ 2,207 $ (2,079 ) $ 128 $ (128 ) $ — December 31, 2014 Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount Assets Derivative contracts - current $ 291,414 $ — $ 291,414 $ — $ 291,414 Derivative contracts - noncurrent 47,003 — 47,003 — 47,003 Total $ 338,417 $ — $ 338,417 $ — $ 338,417 Liabilities Derivative contracts - current $ — $ — $ — $ — $ — Derivative contracts - noncurrent — — — — — Total $ — $ — $ — $ — $ — The Company recorded a loss on commodity derivative contracts of $33.0 million and $85.3 million for the three-month periods ended June 30, 2015 and 2014 , respectively, which includes net cash (receipts) payments upon settlement of $(74.4) million and $13.1 million , respectively. The Company recorded a (gain) loss on commodity derivative contracts of $(16.8) million and $127.8 million for the six -month periods ended June 30, 2015 and 2014 , respectively, which includes net cash (receipts) payments upon settlement of $(211.3) million and $96.4 million , respectively. Included in the net cash payments for the six -month period ended June 30, 2014 are $69.6 million of cash payments related to the settlements of commodity derivative contracts with contractual maturities after the period in which they were settled (“early settlements”) primarily as a result of the sale of the Gulf Properties in February 2014. At June 30, 2015 , the Company’s open commodity derivative contracts consisted of the following: Oil Price Swaps Notional (MBbls) Weighted Average Fixed Price July 2015 - December 2015 1,570 $ 93.02 January 2016 - December 2016 1,464 $ 88.36 Natural Gas Price Swaps Notional (MMcf) Weighted Average Fixed Price July 2015 - December 2015 3,680 $ 4.20 Natural Gas Basis Swaps Notional (MMcf) Weighted Average Fixed Price July 2015 - December 2015 31,280 $ (0.30 ) January 2016 - December 2016 10,980 $ (0.38 ) Oil Collars - Three-way Notional (MBbls) Sold Put Purchased Put Sold Call July 2015 - December 2015 3,128 $78.15 $90.03 $103.65 January 2016 - December 2016 2,556 $83.14 $90.00 $100.85 Natural Gas Collars Notional (MMcf) Collar Range July 2015 - December 2015 509 $4.00 — $8.55

Asset Retirement Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations A reconciliation of the beginning and ending aggregate carrying amounts of the asset retirement obligations for the period from December 31, 2014 to June 30, 2015 is as follows (in thousands): Asset retirement obligations at December 31, 2014 $ 54,402 Liability incurred upon acquiring and drilling wells 860 Liability settled or disposed in current period (369 ) Accretion 2,191 Asset retirement obligations at June 30, 2015 57,084 Less: current portion — Asset retirement obligations, net of current $ 57,084

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Legal Proceedings On April 5, 2011, Wesley West Minerals, Ltd. and Longfellow Ranch Partners, LP filed suit against the Company and SandRidge Exploration and Production, LLC (collectively, the “SandRidge Entities”) in the 83rd District Court of Pecos County, Texas. The plaintiffs, who have leased mineral rights to the SandRidge Entities in Pecos County, allege that the SandRidge Entities have not properly paid royalties on all volumes of natural gas and CO 2 produced from the acreage leased from the plaintiffs. The plaintiffs also allege that the SandRidge Entities have inappropriately failed to pay royalties on CO 2 produced from the plaintiffs' acreage that results from the treatment of natural gas at the Century Plant. The plaintiffs seek approximately $45.5 million in actual damages for the period of time between January 2004 and December 2011, punitive damages and a declaration that the SandRidge Entities must pay royalties on CO 2 produced from the plaintiffs' acreage that results from treatment of natural gas at the Century Plant. The Commissioner of the General Land Office of the State of Texas (“GLO”) is named as an additional defendant in the lawsuit as some of the affected oil and natural gas leases described in the plaintiffs' allegations cover mineral classified lands in which the GLO is entitled to one-half of the royalties attributable to such leases. The GLO has filed a cross-claim against the SandRidge Entities asserting the same claims as the plaintiffs with respect to the leases covering mineral classified lands and seeking approximately $13.0 million in actual damages, inclusive of penalties and interest. On February 5, 2013, the Company received a favorable summary judgment ruling that effectively removes a majority of the plaintiffs' and GLO's claims. On April 29, 2013, the court entered an order allowing for an interlocutory appeal of its summary judgment ruling. The plaintiffs appealed the rulings to the Texas Court of Appeals in El Paso. On November 19, 2014, that Court issued its opinion, which affirmed the trial court’s summary judgment rulings in part, but reversing them in part. The Court of Appeals affirmed the summary judgment rulings in the SandRidge Entities’ favor against the GLO. The Court also affirmed the summary judgment rulings in the SandRidge Entities’ favor against Wesley West Minerals, Ltd., on the largest oil and gas lease involved in the case, which accounted for much of the total damages the plaintiffs are claiming. The Court reversed certain rulings on other leases, thus deciding those matters for the plaintiffs. The parties have petitioned the Supreme Court of Texas for review of the Court of Appeals’ decision. The Company intends to continue to defend the remaining issues in the trial court, as well as future appellate proceedings. At the time of the rulings on summary judgment, the lawsuit was still in the discovery stage and, accordingly, an estimate of reasonably possible losses, if any, associated with the remaining causes of action and those rulings reversed by the Court of Appeals cannot be made until all of the facts, circumstances and legal theories relating to such claims and the SandRidge Entities' defenses are fully disclosed and analyzed. The Company has not established any reserves relating to this action. On August 4, 2011, Patriot Exploration, LLC, Jonathan Feldman, Redwing Drilling Partners, Mapleleaf Drilling Partners, Avalanche Drilling Partners, Penguin Drilling Partners and Gramax Insurance Company Ltd. filed a lawsuit against the Company, SandRidge Exploration and Production, LLC (“SandRidge E&P”) and certain current and former directors and senior executive officers of the Company (collectively, the “defendants”) in the U.S. District Court for the District of Connecticut. On October 28, 2011, the plaintiffs filed an amended complaint alleging substantially the same allegations as those contained in the original complaint. The plaintiffs allege that the defendants made false and misleading statements to U.S. Drilling Capital Management LLC and to the plaintiffs prior to the entry into a participation agreement among Patriot Exploration, LLC, U.S. Drilling Capital Management LLC and SandRidge E&P, which provided for the investment by the plaintiffs in certain of SandRidge E&P's oil and natural gas properties. Pursuant to a settlement agreement reached between the parties, a payment of approximately $4.0 million will be made to the plaintiffs by the Company’s insurer and will be covered by the Company’s applicable directors and officers liability insurance policy. The Company has not established a reserve for such amount. Between December 2012 and March 2013, seven putative shareholder derivative actions were filed in state and federal court in Oklahoma: • Arthur I. Levine v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on December 19, 2012 in the U.S. District Court for the Western District of Oklahoma • Deborah Depuy v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on January 22, 2013 in the U.S. District Court for the Western District of Oklahoma • Paul Elliot, on Behalf of the Paul Elliot IRA R/O, v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on January 29, 2013 in the U.S. District Court for the Western District of Oklahoma • Dale Hefner v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on January 4, 2013 in the District Court of Oklahoma County, Oklahoma • Rocky Romano v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on January 22, 2013 in the District Court of Oklahoma County, Oklahoma • Joan Brothers v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on February 15, 2013 in the U.S. District Court for the Western District of Oklahoma • Lisa Ezell, Jefferson L. Mangus, and Tyler D. Mangus v. Tom L. Ward, et al., and SandRidge Energy, Inc., Nominal Defendant - filed on March 22, 2013 in the U.S. District Court for the Western District of Oklahoma Each lawsuit identified above was filed derivatively on behalf of the Company and names as defendants current and former directors of the Company. The Hefner lawsuit also names as defendants certain current and former directors and senior executive officers of the Company. All seven lawsuits assert overlapping claims - generally that the defendants breached their fiduciary duties, mismanaged the Company, wasted corporate assets, and engaged in, facilitated or approved self-dealing transactions in breach of their fiduciary obligations. The Depuy lawsuit also alleges violations of federal securities laws in connection with the Company allegedly filing and distributing certain misleading proxy statements. The lawsuits seek, among other relief, injunctive relief related to the Company's corporate governance and unspecified damages. On April 10, 2013, the U.S. District Court for the Western District of Oklahoma consolidated the Levine, Depuy, Elliot, Brothers, and Ezell actions (the “Federal Shareholder Derivative Litigation”) under the caption “In re SandRidge Energy, Inc. Shareholder Derivative Litigation,” appointed a lead plaintiff and lead counsel, and ordered the lead plaintiff to file a consolidated complaint by May 1, 2013. On June 3, 2013, the Company and the individual defendants filed their respective motions to dismiss the consolidated complaint. On September 11, 2013, the court granted the defendants’ respective motions to dismiss the consolidated complaint without prejudice, and granted plaintiffs leave to file an amended consolidated complaint. The plaintiffs filed an amended consolidated complaint on October 9, 2013, in which plaintiffs allege that: (i) the Company’s former Chief Executive Officer (“CEO”), Tom Ward, breached his fiduciary duties by usurping corporate opportunities, (ii) certain of the Company’s current and former directors breached their fiduciary duties of care, (iii) Mr. Ward and certain of the Company’s current and former directors wasted corporate assets, (iv) certain entities allegedly affiliated with Mr. Ward aided and abetted Mr. Ward’s breaches of fiduciary duties, (v) Mr. Ward and entities allegedly affiliated with Mr. Ward misappropriated the Company’s confidential and proprietary information, and (vi) entities allegedly affiliated with Mr. Ward were unjustly enriched. On November 15, 2013, the Company and the individual defendants filed their respective motions to dismiss the amended consolidated complaint. On September 22, 2014, the court denied the motion to dismiss filed on behalf of the Company and the director defendants. The court also granted in part and denied in part the respective motions to dismiss filed on behalf of the other defendants. On September 26, 2014, the Board of Directors for the Company formed a Special Litigation Committee (“SLC”), composed of two independent and disinterested Company directors, and delegated absolute and final authority to the SLC to review and investigate the claims alleged by the plaintiffs in the Federal Shareholder Derivative Litigation and in the Hefner action, and to determine whether and how those claims should be asserted on the Company’s behalf. The parties agreed to stay the Hefner action pending the review and investigation by the SLC. On May 8, 2013, the court stayed the Romano action pending further order of the court. On October 31, 2013, the plaintiff filed a motion to lift the stay, which was denied by the court on February 7, 2014. On October 29, 2014, the court granted plaintiff’s application to dismiss the action without prejudice. An estimate of reasonably possible losses associated with both the Federal Shareholder Derivative Litigation and the Hefner action cannot be made at this time. The Company has not established any reserves relating to these actions. On December 5, 2012, James Glitz and Rodger A. Thornberry, on behalf of themselves and all other similarly situated stockholders, filed a putative class action complaint in the U.S. District Court for the Western District of Oklahoma against SandRidge Energy, Inc. and certain current and former executive officers of the Company. On January 4, 2013, Louis Carbone, on behalf of himself and all other similarly situated stockholders, filed a substantially similar putative class action complaint in the same court and against the same defendants. On March 6, 2013, the court consolidated these two actions under the caption “In re SandRidge Energy, Inc. Securities Litigation” (the “Securities Litigation”) and appointed a lead plaintiff and lead counsel. On July 23, 2013, plaintiffs filed a consolidated amended complaint, which asserts a variety of federal securities claims against the Company and certain of its current and former officers and directors, among other defendants, on behalf of a putative class of (a) purchasers of SandRidge common stock during the period from February 24, 2011 to November 8, 2012, (b) purchasers of common units of the Mississippian Trust I in or traceable to its initial public offering on or about April 12, 2011, and (c) purchasers of common units of the Mississippian Trust II (together with the Mississippian Trust I, the “Mississippian Trusts”) in or traceable to its initial public offering on or about April 23, 2012. The claims are based on allegations that the Company, certain of its current and former officers and directors, and the Mississippian Trusts, among other defendants, are responsible for making false and misleading statements, and omitting material information, concerning a variety of subjects, including oil and natural gas reserves, the Company's capital expenditures, and certain transactions entered into by companies allegedly affiliated with the Company's former CEO Tom Ward. The defendants have filed respective motions to dismiss the consolidated amended complaint, some of which are pending before the court. On May 11, 2015, the court dismissed without prejudice plaintiffs’ claims against the Mississippian Trusts and the underwriter defendants. Because the Securities Litigation is in the early stages, an estimate of reasonably possible losses associated with it, if any, cannot be made until the facts, circumstances and legal theories relating to the plaintiffs' claims and defendants’ defenses are fully disclosed and analyzed. The Company has not established any reserves relating to the Securities Litigation. Each of the Mississippian Trusts has requested that the Company indemnify it for any losses it may incur in connection with the Securities Litigation. On July 15, 2013, James Hart and 15 other named plaintiffs filed an amended complaint in the United States District Court for the District of Kansas in an action undertaken individually and on behalf of others similarly situated against SandRidge Energy, Inc., SandRidge Operating Company, SandRidge E&P, SandRidge Midstream, Inc., and Lariat Services, Inc. In their Amended Complaint, plaintiffs allege that the defendants failed to properly calculate overtime pay for the plaintiffs and for other similarly situated current and former employees. The plaintiffs further allege that the defendants required the plaintiffs and other similarly situated current and former employees to engage in work-related activities without pay. The plaintiffs assert claims against the defendants for (i) violations of the Fair Labor Standards Act, (ii) violations of the Kansas Wage Payment Act, (iii) breach of contract, and (iv) fraud, and seek to recover unpaid wages and overtime pay, liquidated damages, statutory penalties, economic damages, compensatory and punitive damages, attorneys’ fees and costs, and both pre- and post-judgment interest. On October 3, 2013, the plaintiffs filed a Motion for Conditional Collective Action Certification and for Judicial Notice to the Class and a Motion to Toll the Statute of Limitations. On October 11, 2013, the defendants filed a Motion to Dismiss and a Motion to Transfer Venue to the United States District Court for the Western District of Oklahoma. On April 2, 2014, the court granted the defendants’ Motion to Dismiss and granted plaintiffs leave to file an amended complaint by April 16, 2014, which they did on such date. On July 1, 2014, the court granted plaintiffs’ Motion for Conditional Collective Action Certification and for Judicial Notice to the Class, and denied plaintiffs’ Motion to Toll the Statute of Limitations. On May 27, 2015, the parties reached an agreement in principle to settle this lawsuit. Pursuant to such agreement, the Company will establish a settlement fund in the amount of approximately $5.0 million from which to pay participating plaintiffs’ claims as well as plaintiffs’ attorneys’ fees. Because the proposed settlement agreement is subject to final negotiations between the parties and court approval, the Company has not established a reserve for this lawsuit. As previously disclosed, on December 18, 2013 the Company received a subpoena duces tecum from the U.S. Department of Justice in connection with an ongoing investigation of possible violations of antitrust laws in connection with the purchase or lease of land, oil or natural gas rights. The transactions that have been the subject of the inquiry date from 2012 and prior years. On April 7, 2015, the U.S. Department of Justice notified the Company that it is a target of a grand jury investigation in the Western District of Oklahoma concerning violations of federal antitrust law. The Company is continuing to respond to the government’s requests in connection with the investigation. The Company is unable to predict the outcome of the government's investigation, or any range of loss that could be associated with the resolution of any possible criminal charges or civil claims that may be brought against the Company; however, any governmental action or resolution thereof could be material to the Company. The Company is cooperating with the investigation. On November 10, 2014, a class action complaint was filed in the U. S. District Court for the Western District of Oklahoma against certain current and former directors and officers of the Company in the case styled Steve Surbaugh vs. SandRidge Energy, Inc., Tom L. Ward, James D. Bennett, Eddie M. LeBlanc, and Randall D. Cooley. The complaint asserts a federal securities class action on behalf of a putative class consisting of all persons other than defendants who purchased SandRidge securities between March 1, 2013, through November 4, 2014, seeking to recover damages allegedly caused by the defendants’ violations of federal securities laws under Sections 10(b) and 20(a) of the Securities Exchange Act of 1934, and Rule 10b-5 promulgated thereunder. The complaint alleges that, throughout the class period, the defendants made materially false and misleading statements regarding SandRidge’s business, operations and future prospects because such statements failed to properly account for the penalties SandRidge accrued under its treating agreement with Occidental Petroleum Corporation (“Occidental”) and, as a result, SandRidge’s financial statements were materially false and misleading during the class period. On November 11, 2014, a class action complaint was filed in the U. S. District Court for the Western District of Oklahoma against certain current and former directors and officers of the Company in the case styled Steven T. Dakil vs. SandRidge Energy, Inc., Tom L. Ward, James D. Bennett, and Eddie M. LeBlanc. The complaint asserts a federal securities class action on behalf of a putative class consisting of all persons other than defendants who purchased or otherwise acquired SandRidge securities between February 28, 2013, and November 3, 2014, seeking to recover damages allegedly caused by the defendants’ violations of federal securities laws under Sections 10(b) and 20(a) of the Securities Exchange Act of 1934, and Rule 10b-5 promulgated thereunder. The complaint alleges that, throughout the class period, defendants made materially false and misleading statements regarding SandRidge’s business, operational and compliance policies. Specifically, plaintiff alleges that defendants made false and/or misleading statements and/or failed to disclose that: (i) SandRidge was improperly accounting for penalties owed to Occidental Petroleum Corp. under a treating agreement on an annual basis when it was required to do so on a quarterly basis; (ii) SandRidge's quarterly and annual financial and operating results for the periods ending December 31, 2012 through June 30, 2014, were overstated and required restatement; (iii) defendant Ward engaged in improper related party transactions; (iv) SandRidge lacked proper internal controls over financial reporting; and (v) as a result of the foregoing, SandRidge’s financial statements were materially false and misleading during the class period. On February 17, 2015, the U.S. District Court for the Western District of Oklahoma consolidated the Surbaugh and Dakil actions. On July 29, 2015, the court dismissed the consolidated action without prejudice to refiling. On June 9, 2015, the Duane & Virginia Lanier Trust, individually and on behalf of all others similarly situated, filed a putative class action complaint in the U.S. District Court for the Western District of Oklahoma against the Company and certain of its current and former officers and directors, among other defendants, on behalf of a putative class of (a) purchasers of common units of the Mississippian Trust I pursuant or traceable to its initial public offering on or about April 7, 2011, and/or at other times during the time period between April 7, 2011, and November 8, 2012 (the “Class Period”), and (b) purchasers of common units of the Mississippian Trust II (together with the Mississippian Trust I, the “Mississippian Trusts”) pursuant or traceable to its initial public offering on or about April 17, 2012, and/or at other times during the Class Period. The claims are based on allegations that the Company, certain of its current and former officers and directors, and the Mississippian Trusts, among other defendants, are responsible for making false and misleading statements, and omitting material information, concerning a variety of subjects, including oil and natural gas reserves and the Company's capital expenditures. The Company and the other defendants intend to defend this lawsuit vigorously. This lawsuit is in the early stages and, accordingly, an estimate of reasonably possible losses associated with this action, if any, cannot be made until the facts, circumstances and legal theories relating to the plaintiffs' claims and the defendants’ defenses are fully disclosed and analyzed. The Company has not established any reserves relating to this action. On July 30, 2015, Barton Gernandt, Jr., individually and on behalf of all others similarly situated, filed a putative class action complaint in the U.S. District Court for the Western District of Oklahoma against the Company and certain of its current and former officers and directors, among other defendants, on behalf of a putative class comprised of all persons, except the named defendants and their immediate family members, who were participants in, or beneficiaries of, the SandRidge Energy, Inc. 401(k) Plan (the “Plan”) at any time between August 2, 2012, and the present, and whose Plan accounts included investments in SandRidge common stock. The Plaintiff purports to bring the action both derivatively on the Plan’s behalf pursuant to ERISA §§ 409 and 502, and as a class action pursuant to Rule 23 of the Federal Rules of Civil Procedure. The plaintiff’s claims are based on allegations that the defendants breached their fiduciary duties owed to the Plan and to the Plan participants by allowing the investment of the Plan’s assets in SandRidge stock when it was otherwise allegedly imprudent to do so based on the financial condition of the Company and the fact the Company’s common stock was artificially inflated because, among other things, the Company materially overstated the amount of oil being produced and the ratio of oil to natural gas in one of its core holdings. The Company intends to defend this lawsuit vigorously. This lawsuit is in the early stages and, accordingly, an estimate of reasonably possible losses associated with this action, if any, cannot be made until the facts, circumstances and legal theories relating to the plaintiffs' claims and the defendants’ defenses are fully disclosed and analyzed. The Company has not established any reserves relating to this action. In addition to the litigation described above, the Company is a defendant in lawsuits from time to time in the normal course of business. While the results of litigation and claims cannot be predicted with certainty, the Company believes the reasonably possible losses of such matters, individually and in the aggregate, are not material. Additionally, the Company believes the probable final outcome of such matters will not have a material adverse effect on the Company’s consolidated financial position, results of operations, cash flows or liquidity. Treating Agreement Commitment The Company is party to a 30 -year treating agreement with Occidental for the removal of CO 2 from natural gas volumes delivered by the Company. Under the agreement, the Company is required to deliver a total of approximately 3,200 Bcf of CO 2 during the agreement period. The Company is obligated to pay Occidental $0.25 per Mcf to the extent minimum annual CO 2 volume requirements are not met. Through December 31, 2014 , the Company had delivered to Occidental 54.7 Bcf of CO 2 , which is 300.1 Bcf less than the cumulative minimum annual CO 2 volume requirements for the same period and had accrued associated annual shortfall penalties of approximately $75.0 million . If such under delivered volumes are not made up with commensurate over deliveries in the future, the Company will be obligated to pay Occidental $0.70 per Mcf (approximately $210.1 million total) in 2041, which amount has not been accrued by the Company as a liability as the Company does not currently believe such payment is probable. Based upon the quantity of CO 2 delivered by the Company during the period from January 1, 2015 through June 30, 2015 and the estimated quantities the Company expects to deliver during the remainder of 2015 , the Company accrued estimated annual under delivery penalties ( $0.25 per Mcf) of approximately $8.7 million and $17.2 million for the three and six -month periods ended June 30, 2015 , respectively. Based on current projected natural gas production levels, the Company expects to accrue between approximately $31.0 million and $38.0 million during the year ending December 31, 2015 for amounts related to the Company’s anticipated shortfall in meeting its 2015 annual delivery obligations. The Company has not accrued any liability for the $0.70 per Mcf fee (approximately $103.9 million total) that would be due in 2041 if the estimated shortfall for the six -month period ended June 30, 2015 is not made up in the future as the Company does not currently believe such payment is probable. If CO 2 volumes delivered to Occidental do not materially increase from current levels, the Company will have the right, beginning in 2020, to reduce future minimum annual CO 2 volume requirements under the agreement by paying Occidental an amount equal to the present value of $0.70 multiplied by such reduced CO 2 volume requirements as designated by the Company. As of June 30, 2015 , if the Company were to cease delivering natural gas for processing and made no future CO 2 deliveries from such date until 2020, the Company would be required to pay annual delivery shortfall penalties, in the aggregate, of approximately $290.2 million for the contract years 2012 through 2019, which includes $92.4 million for penalties incurred through June 30, 2015 . Further, by paying approximately $290.5 million in 2020, which includes the present value of $0.70 multiplied by delivery shortfalls incurred through such date, the Company could adjust the future CO 2 volume requirements to zero. This amount will continue to decrease as future deliveries of CO 2 are made. The Company also may terminate the treating agreement at any time, which would require a termination payment by the Company to Occidental of an amount equal to (a) the present value of $0.70 multiplied by the remaining CO 2 volumes required to be delivered under the agreement, plus (b) Occidental’s current net book value of the Century Plant. The Company has first priority on daily available processing capacity for properly nominated and delivered volumes; however, based on cumulative delivered volumes as of the balance sheet date, if the Company makes no further deliveries from that date until 2025, beginning in 2025 the Century Plant, even if fully utilized, would not have adequate capacity to allow the Company to deliver CO 2 volumes attributable to previously incurred delivery shortfalls at that time. Guarantee of Plugging and Abandonment Obligations In conjunction with the sale of the Gulf Properties, the Company guaranteed on behalf of Fieldwood certain plugging and abandonment obligations associated with the Gulf Properties. The Company submitted a request for release of the guarantee to the BOEM on March 31, 2015 as permitted under the terms of the agreement, and expects to be released from the obligation by the BOEM during the third quarter of 2015. To date, the Company has paid no amounts under this guarantee. See Note 2 for additional information regarding the guarantee. 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 derivative arrangements in order to mitigate a portion of the effect of this price volatility on the Company’s cash flows. See Note 8 for the Company’s open oil and natural gas derivative contracts. Production targets contained in certain gathering and treating agreements require the Company to incur capital expenditures or make associated shortfall payments. The Company depends on cash flows from operating activities and, as necessary, borrowings under its senior credit facility to fund its capital expenditures. Additionally, the Company may use proceeds from the issuance of equity and debt securities in the capital markets and from sales or other monetizations of assets to fund its capital expenditures. Based on current cash balances and cash flows from operating activities, the Company expects to be able to fund its planned capital expenditures budget, debt service requirements and working capital needs in 2015; however, if the current depressed oil or natural gas prices persist for a prolonged period or further 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, which could adversely impact the Company’s ability to comply with the financial covenants under its senior credit facility. See Note 7 for discussion of the financial covenants in the senior credit facility. On July 23, 2015, the Company received notification from the New York Stock Exchange (“NYSE”) that the price of its common stock had fallen below the NYSE’s listing standard, which requires that the average closing price not be less than $1.00 per share over a period of 30 consecutive trading days. The Company intends to consider available alternatives to cure the stock price deficiency and return to compliance with the NYSE continued listing requirement. If the Company’s common stock ultimately were to be delisted, it could adversely impact the Company’s ability to generate funds from equity financing.

Equity

Equity	6 Months Ended
	Jun. 30, 2015
Equity [Abstract]
Equity	Equity Shares of Common Stock Authorized 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 . Preferred Stock Dividends Dividends on the Company’s 8.5% and 7.0% convertible perpetual preferred stock may be paid in cash or with shares of the Company’s common stock at the Company’s election. For the six -month period ended June 30, 2015 , dividends of $11.3 million on the Company’s 8.5% convertible perpetual preferred stock were paid in cash. For the three and six -month periods ended June 30, 2015 , the Company paid a semi-annual dividend of $3.50 per share on its 7.0% convertible perpetual preferred stock by issuing approximately 5.7 million shares of common stock. In accordance with the terms governing the 7.0% convertible perpetual preferred stock, for purposes of the dividend payment, the value of each share issued was determined by multiplying (i) the average volume-weighted share price for the 15 trading day period ending April 28, 2015 by (ii) 95% . 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 , or $2.23 per each of the 3.0 million shares of 7.0% convertible perpetual preferred stock outstanding, that resulted in a difference between the fixed rate semi-annual dividend and the value of shares issued of approximately $3.8 million . This difference was recorded as a reduction to preferred stock dividends in the unaudited condensed consolidated statements of operations for the three and six -month periods ended June 30, 2015 . All dividend payments for the three and six -month periods ended June 30, 2014 on the Company’s 8.5% , 6.0% and 7.0% convertible perpetual preferred stock were paid in cash. Additionally, in the fourth quarter of 2014, all outstanding shares of the 6.0% convertible perpetual preferred stock converted automatically into shares of the Company’s common stock at the then-prevailing conversion rate, resulting in the issuance of approximately 18.4 million shares of common stock. The final dividend payment for the 6.0% convertible preferred stock was made during 2014. Paid and unpaid dividends included in the calculation of loss applicable to the Company’s common stockholders and the Company’s basic loss per share calculation for the three and six -month periods ended June 30, 2015 and 2014 are presented in the accompanying unaudited condensed consolidated statements of operations. See Note 13 for discussion of the Company’s loss per share calculation. Treasury Stock The Company makes required statutory tax payments on behalf of employees when their restricted stock awards vest and then withholds a number of vested shares of common stock having a value on the date of vesting equal to the tax obligation. The following table shows the number of shares withheld for taxes and the associated value of those shares for the six -month periods ended June 30, 2015 and 2014 . These shares were accounted for as treasury stock when withheld and then immediately retired. Six Months Ended June 30, 2015 2014 (In thousands) Number of shares withheld for taxes 1,279 637 Value of shares withheld for taxes $ 2,093 $ 3,865 Stockholder Receivable The Company is party to a settlement agreement relating to a third-party claim against its former CEO under Section 16(b) of the Securities Exchange Act of 1934, as amended. Based on the nature of the settlement as well as the former CEO’s position as an officer of the Company at the time of the settlement, the receivable is classified as a component of additional paid-in capital in the accompanying unaudited condensed consolidated balance sheets. The remaining amount receivable under the agreement as of June 30, 2015 and December 31, 2014 was $2.5 million and is due in two equal installments in October 2015 and October 2016. See Note 15 for discussion of the Company’s share-based compensation.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The Company estimates for each interim reporting period the effective tax rate expected for the full fiscal year and uses that estimated rate in providing for income taxes on a current year-to-date basis. The provision for income taxes consisted of the following components for the three and six -month periods ended June 30, 2015 and 2014 (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Current Federal $ — $ — $ — $ — State 25 (1,194 ) 65 (1,067 ) 25 (1,194 ) 65 (1,067 ) Deferred Federal — — — — State — — — — — — — — Total provision 25 (1,194 ) 65 (1,067 ) Less: income tax provision attributable to noncontrolling interest 19 88 49 170 Total provision attributable to SandRidge Energy, Inc. $ 6 $ (1,282 ) $ 16 $ (1,237 ) 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 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. As a result of the significant weight placed on the Company's cumulative negative earnings position, the Company continued to maintain the full valuation allowance against its net deferred tax asset at June 30, 2015 . Thus the Company’s effective tax rate and tax expense for the three and six -month periods ended June 30, 2015 continue to be low as a result of the Company not recognizing an income tax benefit associated with its net loss from the same periods. Internal Revenue Code (“IRC”) Section 382 addresses company ownership changes and specifically limits the utilization of certain deductions and other tax attributes on an annual basis following an ownership change. The Company experienced ownership changes within the meaning of IRC Section 382 during 2008 and 2010 that subjected certain of the Company’s tax attributes, including $929.4 million of federal net operating loss carryforwards, to the IRC Section 382 limitation. These limitations could result in a material amount of existing loss carryforwards expiring unused. None of these limitations resulted in a current federal tax liability at June 30, 2015 . At both June 30, 2015 and December 31, 2014 , the Company had a liability of approximately $0.1 million for unrecognized tax benefits. The Company does not expect a significant change in its gross unrecognized tax benefits balance within the next twelve months. The Company’s only taxing jurisdiction is the United States (federal and state). The Company’s tax years 2011 to present remain open for federal examination. Additionally, tax years 2005 through 2010 remain subject to examination for the purpose of determining the amount of remaining federal net operating loss and other carryforwards. The number of years open for state tax audits varies, depending on the state, but are generally from three to five years.

Loss per Share

Loss per Share	6 Months Ended
	Jun. 30, 2015
Earnings Per Share [Abstract]
Loss Per Share	Loss per Share The following table summarizes the calculation of weighted average common shares outstanding used in the computation of diluted loss per share, for the three and six -month periods ended June 30, 2015 and 2014 : Net Loss Weighted Average Shares Loss Per Share (In thousands, except per share amounts) Three Months Ended June 30, 2015 Basic loss per share $ (1,375,556 ) 495,153 $ (2.78 ) Effect of dilutive securities Restricted stock and units(1) — — Convertible preferred stock(2) — — Diluted loss per share $ (1,375,556 ) 495,153 $ (2.78 ) Three Months Ended June 30, 2014 Basic loss per share $ (46,775 ) $ 485,318 $ (0.10 ) Effect of dilutive securities Restricted stock(3) — — Convertible preferred stock(4) — — Diluted loss per share $ (46,775 ) 485,318 $ (0.10 ) Six Months Ended June 30, 2015 Basic loss per share $ (2,421,390 ) 486,704 $ (4.98 ) Effect of dilutive securities Restricted stock and units(1) — — Convertible preferred stock(2) — — Diluted loss per share $ (2,421,390 ) 486,704 $ (4.98 ) Six Months Ended June 30, 2014 Basic loss per share $ (196,993 ) 485,059 $ (0.41 ) Effect of dilutive securities Restricted stock(3) — — Convertible preferred stock(4) — — Diluted loss per share $ (196,993 ) 485,059 $ (0.41 ) ____________________ (1) No incremental shares of potentially dilutive restricted stock awards or units were included for the three and six -month periods ended June 30, 2015 as their effect was antidilutive under the treasury stock method. (2) Potential common shares related to the Company’s outstanding 8.5% and 7.0% convertible perpetual preferred stock covering 71.7 million shares for the three and six -month periods ended June 30, 2015 , were excluded from the computation of loss per share because their effect would have been antidilutive under the if-converted method. (3) Restricted stock awards covering 2.0 million and 2.6 million shares for the three and six -month periods ended June 30, 2014 , respectively, were excluded from the computation of loss per share because their effect would have been antidilutive. (4) Potential common shares related to the Company’s outstanding 8.5% , 6.0% and 7.0% convertible perpetual preferred stock covering 90.1 million shares for the three and six -month periods ended June 30, 2014 , were excluded from the computation of loss per share because their effect would have been antidilutive under the if-converted method. See Note 7 for discussion of common stock issued in exchange for Senior Unsecured Notes and Note 11 for discussion of common stock issued in payment of preferred stock dividends.

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2015
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions Former Chairman and CEO Severance. Included in other current liabilities and other long-term obligations in the accompanying unaudited condensed consolidated balance sheets as of June 30, 2015 and December 31, 2014 are amounts totaling $2.4 million and $3.1 million , respectively, due to the Company’s former Chairman and CEO under the terms of his employment agreement. Such amounts are to be paid in monthly installments through December 2016. See Note 11 for discussion of the stockholder receivable due from the Company’s former Chairman and CEO. 2014 Divestiture. See Note 2 for discussion of the sale of the Gulf Properties to Fieldwood and the Company’s guarantee on behalf of Fieldwood of certain associated plugging and abandonment obligations associated with the Gulf Properties. Fieldwood is a portfolio company of Riverstone Holdings LLC, affiliates of which own a significant number of shares of the Company’s common stock. Acquisition of Ownership Interest. In March 2014, the Company purchased the additional ownership interest owned by its partner in GRLP and Genpar, which was deemed a related party at the time. See Note 3 for additional discussion.

Share-Based Compensation

Share-Based Compensation	6 Months Ended
	Jun. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-Based Compensation	Share-Based Compensation The Company issues share-based compensation awards including restricted common stock awards, restricted stock units, performance units and performance share units under the SandRidge Energy, Inc. 2009 Incentive Plan (the “Plan”). Total share-based compensation expense is measured using the grant date fair value for equity-classified awards and using the fair value at period end for liability-classified awards. Restricted Common Stock Awards The Company’s restricted common stock awards generally vest over a four -year period, subject to certain conditions, and are valued based upon the market value of the Company’s common stock on the date of grant. The following table presents a summary of the Company’s unvested restricted stock awards. Number of Shares Weighted- Average Grant Date Fair Value (In thousands) Unvested restricted shares outstanding at December 31, 2014 8,556 $ 6.39 Granted 662 $ 1.78 Vested (3,030 ) $ 6.34 Forfeited / Canceled (575 ) $ 6.39 Unvested restricted shares outstanding at June 30, 2015 5,613 $ 5.88 As of June 30, 2015 , the Company’s unrecognized compensation cost related to unvested restricted stock awards was $25.0 million . Such cost is expected to be recognized over a weighted-average period of 2.0 years. The Company’s restricted stock awards are equity-classified awards. Restricted Stock Units During the six -month period ended June 30, 2015 , the Company granted restricted stock units that vest over two or four-year periods and will be settled in cash, shares of Company common stock or a combination of common stock and cash. Four-Year Restricted Stock Units . The following table presents a summary of the Company’s unvested restricted stock units which vest ratably over a four -year period from the date of grant. These restricted stock units may be settled in shares of the Company’s common stock, cash or some combination of common stock and cash at the Company’s election and were valued at June 30, 2015 based upon the Company’s period end common stock price. Number of Units Fair Value per Unit at June 30, 2015 (In thousands) Unvested units outstanding at December 31, 2014 — Granted 8,945 Vested (827 ) Forfeited / Canceled (543 ) Unvested units outstanding at June 30, 2015 7,575 $ 0.88 All four-year restricted stock units that vested during the six-month period ended June 30, 2015 were settled by the issuance of common stock. As of June 30, 2015 , the Company’s unrecognized compensation cost related to unvested four-year restricted stock units was $5.4 million . Such cost is expected to be recognized over a weighted-average period of 2.1 years. The four-year restricted stock units are liability-classified awards. Two-Year Restricted Stock Units. The following table presents a summary of the Company’s unvested restricted stock units which vest over a two -year period ( 40% at the end of the first year and 60% at the end of the second year). These restricted stock units will be settled in cash at the end of each vesting period for an amount based on the Company’s common stock price as of the vesting date. The restricted stock units were valued based upon the Company’s period end common stock price, discounted using a credit spread ( 3.6% at June 30, 2015 ) that was determined based upon an analysis of the historical option adjusted spread for the Company’s outstanding senior notes and the outstanding long-term debt of comparable companies. Number of Units Fair Value per Unit at June 30, 2015 (In thousands) Unvested units outstanding at December 31, 2014 — Granted 2,398 Vested — Forfeited / Canceled (122 ) Unvested units outstanding at June 30, 2015 2,276 $ 0.51 – $ 0.73 As of June 30, 2015 , the Company’s unrecognized compensation cost related to unvested two-year restricted stock units was $1.0 million . Such cost is expected to be recognized over a weighted-average period of 1.1 years. The two-year restricted stock units are liability-classified awards. Performance Units and Performance Share Units The Company periodically grants performance units and performance share units to certain members of senior management which vest ratably over a performance period of approximately three years with cash settlements, if any, occurring at the end of the performance period. The value, and ultimate cash settlement, of the performance units is determined based upon the Company’s total shareholder return relative to that of a predetermined peer group over a specific performance period. The Company’s performance units and performance share units are liability-classified awards. The performance units and performance share units are valued for accounting purposes using a Monte Carlo simulation based on certain assumptions including (i) volatility assumption based on the historical realized price volatility of the Company’s common stock and the common stock of the predetermined peer group and (ii) a risk-free interest rate based on the U.S. Treasury bond yield for a term commensurate with the approximate remaining vesting period for each grant. Performance Units. The following table presents a summary of the fair values of the performance units granted during the years ended December 31, 2014 and 2013 and the related assumptions for all outstanding performance units at June 30, 2015 and December 31, 2014 . June 30, 2015 December 31, 2014 Expected price volatility range 25.7 % - 89.7 % 26.6 % - 86.6 % Weighted-average risk-free interest rate 0.3 % 0.5 % Weighted-average fair value per unit $ 1.41 $ 13.85 Performance unit activity for the six-month period ended June 30, 2015 was as follows: Number of Performance Units (In thousands) Outstanding at December 31, 2014 66 Granted — Forfeited /canceled — Outstanding at June 30, 2015 66 Performance period ending December 31, 2015 Vested 22 Unvested 6 Performance period ending December 31, 2016 Vested 15 Unvested 23 Performance Share Units. During the six-month period ended June 30, 2015 , the Company granted performance share units to certain members of senior management. The following table presents a summary of the fair values of the performance share units granted and the related assumptions for all outstanding performance share units at June 30, 2015 . June 30, 2015 Expected price volatility range 29.0 % - 77.2 % Weighted-average risk-free interest rate 0.9 % Weighted-average fair value per unit $ 0.52 P erformance share unit activity for the six-month period ended June 30, 2015 was as follows: Number of Performance Share Units (In thousands) Outstanding at December 31, 2014 — Granted 2,044 Forfeited /canceled (151 ) Outstanding at June 30, 2015 1,893 Performance period ending December 31, 2017 Vested — Unvested 1,893 Allocation of Share-Based Compensation 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, cost of sales and midstream and marketing expenses in the unaudited condensed consolidated statements of operations. For the three and six -month periods ended June 30, 2015 , the Company recognized share-based compensation expense of $8.2 million and $13.9 million , net of $1.3 million and $2.6 million capitalized, respectively. For the three and six -month periods ended June 30, 2014 , the Company recognized share-based compensation expense of $7.3 million and $15.5 million , net of $1.9 million and $3.1 million capitalized, respectively.

Business Segment Information

Business Segment Information	6 Months Ended
	Jun. 30, 2015
Segment Reporting [Abstract]
Business Segment Information	Business Segment Information The Company has three reportable segments: exploration and production, drilling and oil field services and midstream services. These segments represent the Company’s three main business units, each offering different products and services. The exploration and production segment is engaged in the exploration and production of oil and natural gas properties and includes the activities of the Royalty Trusts. The drilling and oil field services segment is engaged in the contract drilling of oil and natural gas wells and provides various oil field services. The midstream services segment is engaged in the purchasing, gathering, treating and selling of natural gas and coordinates the delivery of electricity to the Company’s exploration and production operations in the Mid-Continent. The All Other columns in the tables below includes items not related to the Company’s reportable segments, including the Company’s corporate operations. Management evaluates the performance of the Company’s business segments based on income (loss) from operations. Summarized financial information concerning the Company’s segments is shown in the following table (in thousands): Exploration and Production(1) Drilling and Oil Field Services(2)(3) Midstream Services All Other Consolidated Total Three Months Ended June 30, 2015 Revenues $ 214,534 $ 17,161 $ 20,782 $ 1,228 $ 253,705 Inter-segment revenue (2 ) (11,920 ) (12,176 ) — (24,098 ) Total revenues $ 214,532 $ 5,241 $ 8,606 $ 1,228 $ 229,607 Loss from operations $ (1,511,600 ) $ (3,754 ) $ (3,154 ) $ (16,575 ) $ (1,535,083 ) Interest expense (23 ) — — (73,704 ) (73,727 ) Gain on extinguishment of debt — — — 17,934 17,934 Other income, net 1,630 4 9 527 2,170 Loss before income taxes $ (1,509,993 ) $ (3,750 ) $ (3,145 ) $ (71,818 ) $ (1,588,706 ) Capital expenditures(4) $ 151,440 $ 598 $ 8,249 $ 7,279 $ 167,566 Depreciation, depletion, amortization and accretion $ 95,430 $ 5,000 $ 2,793 $ 4,694 $ 107,917 Three Months Ended June 30, 2014 Revenues $ 339,906 $ 51,891 $ 38,420 $ 1,105 $ 431,322 Inter-segment revenue — (33,062 ) (23,546 ) — (56,608 ) Total revenues $ 339,906 $ 18,829 $ 14,874 $ 1,105 $ 374,714 Income (loss) from operations $ 69,782 $ (2,347 ) $ (2,345 ) $ (23,011 ) $ 42,079 Interest expense (4 ) — — (61,859 ) (61,863 ) Other (expense) income, net (49 ) (75 ) — 1,462 1,338 Income (loss) before income taxes $ 69,729 $ (2,422 ) $ (2,345 ) $ (83,408 ) $ (18,446 ) Capital expenditures(4) $ 356,568 $ 6,654 $ 5,808 $ 7,907 $ 376,937 Depreciation, depletion, amortization and accretion $ 98,357 $ 7,661 $ 2,509 $ 5,216 $ 113,743 Six Months Ended June 30, 2015 Revenues $ 410,277 $ 41,790 $ 42,312 $ 2,195 $ 496,574 Inter-segment revenue (13 ) (26,704 ) (24,942 ) — (51,659 ) Total revenues $ 410,264 $ 15,086 $ 17,370 $ 2,195 $ 444,915 Loss from operations $ (2,565,759 ) $ (11,526 ) $ (7,027 ) $ (39,227 ) $ (2,623,539 ) Interest expense, net (40 ) — — (136,529 ) (136,569 ) Gain on extinguishment of debt — — — 17,934 17,934 Other income, net 1,176 — 13 445 1,634 Loss before income taxes $ (2,564,623 ) $ (11,526 ) $ (7,014 ) $ (157,377 ) $ (2,740,540 ) Capital expenditures(4) $ 453,503 $ 2,472 $ 16,681 $ 15,100 $ 487,756 Depreciation, depletion, amortization and accretion $ 202,640 $ 10,760 $ 5,473 $ 9,578 $ 228,451 At June 30, 2015 Total assets $ 3,708,676 $ 91,905 $ 221,064 $ 1,413,403 $ 5,435,048 Exploration and Production(1) Drilling and Oil Field Services(2)(3) Midstream Services All Other Consolidated Total Six Months Ended June 30, 2014 Revenues $ 747,244 $ 98,971 $ 84,715 $ 2,075 $ 933,005 Inter-segment revenue — (63,039 ) (52,196 ) — (115,235 ) Total revenues $ 747,244 $ 35,932 $ 32,519 $ 2,075 $ 817,770 Income (loss) from operations $ 13,306 $ (5,449 ) $ (3,756 ) $ (44,352 ) $ (40,251 ) Interest income (expense), net 139 — — (124,045 ) (123,906 ) Other (expense) income, net (234 ) (473 ) — 4,139 3,432 Income (loss) before income taxes $ 13,211 $ (5,922 ) $ (3,756 ) $ (164,258 ) $ (160,725 ) Capital expenditures(4) $ 620,809 $ 7,275 $ 11,766 $ 12,860 $ 652,710 Depreciation, depletion, amortization and accretion $ 219,398 $ 15,372 $ 4,950 $ 10,476 $ 250,196 At December 31, 2014 Total assets $ 6,273,802 $ 115,083 $ 219,691 $ 650,649 $ 7,259,225 ____________________ (1) (Loss) income from operations includes full cost ceiling limitation impairments of $1.5 billion and $2.6 billion for the three and six -month periods ended June 30, 2015 , respectively, and $164.8 million for the six -month period ended June 30, 2014 . (2) (Loss) income from operations includes an impairment of $3.1 million on certain drilling assets held for sale for the three and six -month periods ended June 30, 2014 . (3) Drilling and oilfield services assets with a net book value of approximately $20.0 million were reclassified as assets held for sale during the three-month period ended June 30, 2015 . (4) On an accrual basis and exclusive of acquisitions.

Condensed Consolidating Financi

Condensed Consolidating Financial Information	6 Months Ended
	Jun. 30, 2015
Condensed Consolidating Financial Statements Disclosure [Abstract]
Condensed Consolidating Financial Information	Condensed Consolidating Financial Information The Company provides condensed consolidating financial information for its subsidiaries that are guarantors of its registered debt. As of June 30, 2015 , the subsidiary guarantors, which are 100% owned by the Company, have jointly and severally guaranteed, on a full, unconditional and unsecured basis, the Company’s outstanding Senior Unsecured Notes. The subsidiary guarantees (i) rank equally in right of payment with all of the existing and future senior debt of the subsidiary guarantors; (ii) rank senior to all of the existing and future subordinated debt of the subsidiary guarantors; (iii) are effectively subordinated in right of payment to any existing or future secured obligations of the subsidiary guarantors to the extent of the value of the assets securing such obligations; (iv) are structurally subordinated to all debt and other obligations of the subsidiaries of the guarantors who are not themselves subsidiary guarantors; and (v) are only released under certain customary circumstances. The Company’s subsidiary guarantors guarantee payments of principal and interest under the Company’s registered notes. Certain of the Company’s wholly owned subsidiaries that were sold in February 2014, as discussed in Note 2 , guaranteed the Company’s registered debt. Upon the closing of the sale, these subsidiaries were released from their guarantees. The condensed consolidating financial information in the tables below reflects these subsidiaries’ financial information through the date of the sale. The following condensed consolidating financial information represents the financial information of SandRidge Energy, Inc., its wholly owned subsidiary guarantors and its non-guarantor subsidiaries, prepared on the equity basis of accounting. The non-guarantor subsidiaries, including consolidated VIEs, majority-owned subsidiaries and certain immaterial wholly owned subsidiaries, are included in the non-guarantors column in the tables below. The financial information may not necessarily be indicative of the financial position, results of operations or cash flows had the subsidiary guarantors operated as independent entities. Condensed Consolidating Balance Sheets June 30, 2015 Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) ASSETS Current assets Cash and cash equivalents $ 970,115 $ 4,440 $ 9,062 $ — $ 983,617 Accounts receivable, net 7 228,493 9,227 (7 ) 237,720 Intercompany accounts receivable 1,026,442 1,341,801 35,566 (2,403,809 ) — Derivative contracts — 120,575 14,241 (14,241 ) 120,575 Prepaid expenses — 9,926 12 — 9,938 Other current assets — 25,985 — — 25,985 Total current assets 1,996,564 1,731,220 68,108 (2,418,057 ) 1,377,835 Property, plant and equipment, net — 3,334,417 551,984 — 3,886,401 Investment in subsidiaries 4,307,423 7,878 — (4,315,301 ) — Derivative contracts — 23,470 — — 23,470 Other assets 135,828 16,785 631 (5,902 ) 147,342 Total assets $ 6,439,815 $ 5,113,770 $ 620,723 $ (6,739,260 ) $ 5,435,048 LIABILITIES AND EQUITY Current liabilities Accounts payable and accrued expenses $ 177,231 $ 316,001 $ 1,450 $ (7 ) $ 494,675 Intercompany accounts payable 1,328,602 1,040,026 35,181 (2,403,809 ) — Derivative contracts — 14,343 — (14,241 ) 102 Deferred tax liability 52,763 — — — 52,763 Other current liabilities — 3,791 — — 3,791 Total current liabilities 1,558,596 1,374,161 36,631 (2,418,057 ) 551,331 Investment in subsidiaries 914,164 273,921 — (1,188,085 ) — Long-term debt 4,401,541 — — (5,902 ) 4,395,639 Derivative contracts — 26 — — 26 Asset retirement obligations — 57,084 — — 57,084 Other long-term obligations 77 15,319 — — 15,396 Total liabilities 6,874,378 1,720,511 36,631 (3,612,044 ) 5,019,476 Equity SandRidge Energy, Inc. stockholders’ equity (434,563 ) 3,393,259 584,092 (3,977,351 ) (434,563 ) Noncontrolling interest — — — 850,135 850,135 Total equity (434,563 ) 3,393,259 584,092 (3,127,216 ) 415,572 Total liabilities and equity $ 6,439,815 $ 5,113,770 $ 620,723 $ (6,739,260 ) $ 5,435,048 December 31, 2014 Parent Guarantors(1) Non-Guarantors(2) Eliminations(1)(2) Consolidated (In thousands) ASSETS Current assets Cash and cash equivalents $ 170,468 $ 1,398 $ 9,387 $ — $ 181,253 Accounts receivable, net 7 299,764 30,313 (7 ) 330,077 Intercompany accounts receivable 751,376 1,339,152 41,679 (2,132,207 ) — Derivative contracts — 284,825 45,043 (38,454 ) 291,414 Prepaid expenses — 7,971 10 — 7,981 Other current assets — 21,193 — — 21,193 Total current assets 921,851 1,954,303 126,432 (2,170,668 ) 831,918 Property, plant and equipment, net — 5,137,702 1,077,355 — 6,215,057 Investment in subsidiaries 6,606,198 25,944 — (6,632,142 ) — Derivative contracts — 47,003 — — 47,003 Other assets 152,286 18,197 666 (5,902 ) 165,247 Total assets $ 7,680,335 $ 7,183,149 $ 1,204,453 $ (8,808,712 ) $ 7,259,225 LIABILITIES AND EQUITY Current liabilities Accounts payable and accrued expenses $ 201,368 $ 477,399 $ 4,632 $ (7 ) $ 683,392 Intercompany accounts payable 1,315,667 780,645 35,895 (2,132,207 ) — Derivative contracts — 38,454 — (38,454 ) — Deferred tax liability 95,843 — — — 95,843 Other current liabilities — 5,216 — — 5,216 Total current liabilities 1,612,878 1,301,714 40,527 (2,170,668 ) 784,451 Investment in subsidiaries 928,217 134,013 — (1,062,230 ) — Long-term debt 3,201,338 — — (5,902 ) 3,195,436 Asset retirement obligations — 54,402 — — 54,402 Other long-term obligations 77 15,039 — — 15,116 Total liabilities 5,742,510 1,505,168 40,527 (3,238,800 ) 4,049,405 Equity SandRidge Energy, Inc. stockholders’ equity 1,937,825 5,677,981 1,163,926 (6,841,907 ) 1,937,825 Noncontrolling interest — — — 1,271,995 1,271,995 Total equity 1,937,825 5,677,981 1,163,926 (5,569,912 ) 3,209,820 Total liabilities and equity $ 7,680,335 $ 7,183,149 $ 1,204,453 $ (8,808,712 ) $ 7,259,225 ____________________ (1) Amounts presented as property, plant and equipment have been revised to include approximately $150.4 million previously misclassified as investment in subsidiary. (2) Amounts previously misclassified as property, plant and equipment and SandRidge Energy, Inc. stockholders’ equity have been reduced by approximately $150.4 million and are now presented as Guarantor property, plant and equipment. Condensed Consolidating Statements of Operations Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Three Months Ended June 30, 2015 Total revenues $ — $ 203,591 $ 26,016 $ — $ 229,607 Expenses Direct operating expenses — 95,832 2,934 — 98,766 General and administrative 61 37,379 942 — 38,382 Depreciation, depletion, amortization and accretion — 98,416 9,501 — 107,917 Impairment — 1,164,834 324,557 — 1,489,391 Loss on derivative contracts — 29,067 3,937 — 33,004 Gain on sale of assets — (2,770 ) — — (2,770 ) Total expenses 61 1,422,758 341,871 — 1,764,690 (Loss) from operations (61 ) (1,219,167 ) (315,855 ) — (1,535,083 ) Equity earnings from subsidiaries (1,312,652 ) (95,545 ) — 1,408,197 — Interest expense (73,703 ) (24 ) — — (73,727 ) Gain on extinguishment of debt 17,934 — — — 17,934 Other income, net — 2,084 86 — 2,170 Loss before income taxes (1,368,482 ) (1,312,652 ) (315,769 ) 1,408,197 (1,588,706 ) Income tax expense — — 25 — 25 Net loss (1,368,482 ) (1,312,652 ) (315,794 ) 1,408,197 (1,588,731 ) Less: net loss attributable to noncontrolling interest — — — (220,249 ) (220,249 ) Net loss attributable to SandRidge Energy, Inc. $ (1,368,482 ) $ (1,312,652 ) $ (315,794 ) $ 1,628,446 $ (1,368,482 ) Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Three Months Ended June 30, 2014 Total revenues $ — $ 314,521 $ 60,205 $ (12 ) $ 374,714 Expenses Direct operating expenses — 93,597 4,931 (12 ) 98,516 General and administrative 71 30,481 1,363 — 31,915 Depreciation, depletion, amortization and accretion — 99,237 14,506 — 113,743 Impairment — 3,133 — — 3,133 Loss on derivative contracts — 67,509 17,783 — 85,292 Loss on sale of assets — 36 — — 36 Total expenses 71 293,993 38,583 (12 ) 332,635 (Loss) income from operations (71 ) 20,528 21,622 — 42,079 Equity earnings from subsidiaries 27,725 5,863 — (33,588 ) — Interest expense (61,859 ) (4 ) — — (61,863 ) Other income, net — 1,338 — — 1,338 (Loss) income before income taxes (34,205 ) 27,725 21,622 (33,588 ) (18,446 ) Income tax (benefit) expense (1,311 ) — 117 — (1,194 ) Net (loss) income (32,894 ) 27,725 21,505 (33,588 ) (17,252 ) Less: net income attributable to noncontrolling interest — — — 15,642 15,642 Net (loss) income attributable to SandRidge Energy, Inc. $ (32,894 ) $ 27,725 $ 21,505 $ (49,230 ) $ (32,894 ) Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Six Months Ended June 30, 2015 Total revenues $ — $ 396,112 $ 48,811 $ (8 ) $ 444,915 Expenses Direct operating expenses — 207,950 5,770 (8 ) 213,712 General and administrative 117 72,598 1,816 — 74,531 Depreciation, depletion, amortization and accretion — 208,269 20,182 — 228,451 Impairment — 2,068,069 505,188 — 2,573,257 Gain on derivative contracts — (15,042 ) (1,781 ) — (16,823 ) Gain on sale of assets — (4,670 ) (4 ) — (4,674 ) Total expenses 117 2,537,174 531,171 (8 ) 3,068,454 Loss from operations (117 ) (2,141,062 ) (482,360 ) — (2,623,539 ) Equity earnings from subsidiaries (2,284,723 ) (145,166 ) — 2,429,889 — Interest expense (136,529 ) (40 ) — — (136,569 ) Gain on extinguishment of debt 17,934 — — — 17,934 Other income, net — 1,545 89 — 1,634 Loss before income taxes (2,403,435 ) (2,284,723 ) (482,271 ) 2,429,889 (2,740,540 ) Income tax expense — — 65 — 65 Net loss (2,403,435 ) (2,284,723 ) (482,336 ) 2,429,889 (2,740,605 ) Less: net loss attributable to noncontrolling interest — — — (337,170 ) (337,170 ) Net loss attributable to SandRidge Energy, Inc. $ (2,403,435 ) $ (2,284,723 ) $ (482,336 ) $ 2,767,059 $ (2,403,435 ) Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Six Months Ended June 30, 2014 Total revenues $ — $ 693,570 $ 124,299 $ (99 ) $ 817,770 Expenses Direct operating expenses — 232,018 9,741 (99 ) 241,660 General and administrative 220 67,426 2,807 — 70,453 Depreciation, depletion, amortization and accretion — 219,814 30,382 — 250,196 Impairment — 125,599 42,313 — 167,912 Loss on derivative contracts — 101,611 26,172 — 127,783 Loss on sale of assets — 17 — — 17 Total expenses 220 746,485 111,415 (99 ) 858,021 (Loss) income from operations (220 ) (52,915 ) 12,884 — (40,251 ) Equity earnings from subsidiaries (46,259 ) 3,086 — 43,173 — Interest (expense) income (124,045 ) 139 — — (123,906 ) Other income, net — 3,431 1 — 3,432 (Loss) income before income taxes (170,524 ) (46,259 ) 12,885 43,173 (160,725 ) Income tax (benefit) expense (1,294 ) — 227 — (1,067 ) Net (loss) income (169,230 ) (46,259 ) 12,658 43,173 (159,658 ) Less: net income attributable to noncontrolling interest — — — 9,572 9,572 Net (loss) income attributable to SandRidge Energy, Inc. $ (169,230 ) $ (46,259 ) $ 12,658 $ 33,601 $ (169,230 ) Condensed Consolidating Statements of Cash Flows Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Six Months Ended June 30, 2015 Net cash (used in) provided by operating activities $ (122,181 ) $ 344,778 $ 65,902 $ 30,495 $ 318,994 Cash flows from investing activities Capital expenditures for property, plant, and equipment — (636,822 ) — — (636,822 ) Other — (65,989 ) 5 73,971 7,987 Net cash (used in) provided by investing activities — (702,811 ) 5 73,971 (628,835 ) Cash flows from financing activities Proceeds from borrowings 2,190,000 — — — 2,190,000 Repayments of borrowings (940,000 ) — — — (940,000 ) Distributions to unitholders — — (97,498 ) 12,808 (84,690 ) Intercompany (advances) borrowings, net (275,066 ) 276,384 (1,318 ) — — Other (53,106 ) 84,691 32,584 (117,274 ) (53,105 ) Net cash provided by (used in) financing activities 921,828 361,075 (66,232 ) (104,466 ) 1,112,205 Net increase (decrease) in cash and cash equivalents 799,647 3,042 (325 ) — 802,364 Cash and cash equivalents at beginning of year 170,468 1,398 9,387 — 181,253 Cash and cash equivalents at end of period $ 970,115 $ 4,440 $ 9,062 $ — $ 983,617 Parent(1) Guarantors(1) Non-Guarantors Eliminations Consolidated (In thousands) Six Months Ended June 30, 2014 Net cash (used in) provided by operating activities $ (119,006 ) $ 228,860 $ 126,424 $ (5,486 ) $ 230,792 Cash flows from investing activities Capital expenditures for property, plant, and equipment — (656,699 ) — — (656,699 ) Proceeds from sale of assets — 707,799 — — 707,799 Other — (104,286 ) 1,061 86,672 (16,553 ) Net cash (used in) provided by investing activities — (53,186 ) 1,061 86,672 34,547 Cash flows from financing activities Distributions to unitholders — — (127,985 ) 24,843 (103,142 ) Intercompany borrowings (advances), net 257,498 (257,879 ) 381 — — Other (33,364 ) 82,441 (1,150 ) (106,029 ) (58,102 ) Net cash provided by (used in) financing activities 224,134 (175,438 ) (128,754 ) (81,186 ) (161,244 ) Net increase (decrease) in cash and cash equivalents 105,128 236 (1,269 ) — 104,095 Cash and cash equivalents at beginning of year 805,505 1,013 8,145 — 814,663 Cash and cash equivalents at end of period $ 910,633 $ 1,249 $ 6,876 $ — $ 918,758 ____________________ (1) Net cash (used in) provided by operating activities for the Parent has been corrected to exclude $382.7 million in intercompany transactions, and a corresponding increase for Guarantors for this same line item. In addition, Intercompany borrowings (advances), net has been corrected for the Parent to include approximately $382.7 million of intercompany transactions, and a corresponding decrease for Guarantors for the same line item. The changes did not result in any changes to consolidated net cash provided by operating activities or net cash used in financing activities.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2015
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Royalty Trust Distributions . On July 30, 2015 , the Royalty Trusts announced quarterly distributions for the three-month period ended June 30, 2015 . The following distributions are expected to be paid on or before August 28, 2015 to holders of record as of the close of business on August 14, 2015 (in thousands): Royalty Trust Total Distribution Amount Distributed to Third-Party Unitholders Mississippian Trust I $ 8,428 $ 6,162 Permian Trust 16,656 16,656 Mississippian Trust II 9,361 7,794 Total $ 34,445 $ 30,612

Basis of Presentation (Policies

Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2015
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 region of the United States. The Company owns and operates additional interests in west Texas. The Company also operates businesses and infrastructure systems that are complementary to its primary exploration and production activities, including gas gathering and processing facilities, marketing operations, a saltwater gathering and disposal system, an electrical transmission system and a drilling and related oil field services business.
Principles of Consolidation	Principles of Consolidation. The consolidated financial statements include the accounts of the Company and its wholly owned or majority owned subsidiaries and variable interest entities (“VIEs”) for which the Company is the primary beneficiary. Noncontrolling interest represents third-party ownership interests in the Company’s subsidiaries and consolidated VIEs and is included as a component of equity in the consolidated balance sheets and consolidated statement of changes in equity. All significant intercompany accounts and transactions have been eliminated in consolidation.
Variable Interest Entities	Variable Interest Entities. An entity is referred to as a VIE if it possesses one of the following criteria: (i) it is thinly capitalized, (ii) the residual equity holders do not control the entity, (iii) the equity holders are shielded from economic losses, (iv) the equity holders do not participate fully in the entity’s residual economics, or (v) the entity was established with non-substantive voting interests. The Company consolidates a VIE when it has determined it is the primary beneficiary, which requires significant judgment. The primary beneficiary of a VIE is that variable interest holder possessing a controlling financial interest through (i) its power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and (ii) its obligation to absorb losses or its right to receive benefits from the VIE that could potentially be significant to the VIE. In order to determine whether the Company owns a variable interest in a VIE and the significance of the variable interest, the Company performs a qualitative analysis of the entity’s design, organizational structure, primary decision makers and related financial agreements. In addition to the VIEs that the Company consolidates, the Company also holds a variable interest in another VIE that is not consolidated as it was determined that the Company is not the entity’s primary beneficiary. The Company monitors both consolidated and unconsolidated VIEs to determine if any events have occurred that could cause the primary beneficiary to change. See Note 3 for discussion of the Company’s significant associated VIEs.
Interim Financial Statements	Interim Financial Statements. The accompanying unaudited condensed consolidated financial statements as of December 31, 2014 have been derived from the audited financial statements contained in the Company’s 2014 Form 10-K. The unaudited interim condensed consolidated financial statements have been prepared in accordance with the accounting policies stated in the audited consolidated financial statements contained in the 2014 Form 10-K. Certain information and disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) have been condensed or omitted, although the Company believes that the disclosures contained herein are adequate to make the information presented not misleading. In the opinion of management, the accompanying financial statements include all adjustments, which consist of normal recurring adjustments, necessary to state fairly the information in the Company’s accompanying unaudited condensed consolidated financial statements. These unaudited condensed consolidated financial statements should be read in conjunction with the financial statements and notes thereto included in the 2014 Form 10-K. Significant Accounting Policies. For a description of the Company’s significant accounting policies, see Note 1 of the consolidated financial statements included in the 2014 Form 10-K.
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 accompanying unaudited condensed consolidated financial statements in conformity with GAAP 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; cash flow estimates used in the valuation of guarantees; impairment tests of long-lived assets; depreciation, depletion and amortization; asset retirement obligations; assignments of fair value and allocations of purchase price in connection with business combinations; 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.
Recent Accounting Pronouncements	Recent Accounting Pronouncements. In April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-08, “Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity”, which amends the definition of a discontinued operations to elevate the threshold for a disposal transaction to qualify as a discontinued operation and requires entities to provide additional disclosures for disposal transactions that do not meet the discontinued operations criteria. The guidance is effective prospectively for all disposals (except disposals classified as held for sale before the adoption date) or components initially classified as held for sale in periods beginning on or after December 15, 2014, with early adoption permitted. The guidance was adopted January 1, 2015 and had no impact for the six -month period ended June 30, 2015 . Recent Accounting Pronouncements Not Yet Adopted. In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers”, which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance, including industry-specific guidance. The core principle requires that an entity recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. Certain of the provisions also amend or supersede existing guidance applicable to the recognition of a gain or loss on transfers of nonfinancial assets that are not an output of an entity’s ordinary activities, including sales of property, plant and equipment and real estate. The requirements of the guidance are effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period with an option of using either a full retrospective or a modified approach for adoption. The Company is currently evaluating the effect, if any, that the updated standard will have on its consolidated financial statements and related disclosures. In August 2014, the FASB issued ASU 2014-15, “Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern,” which provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued. An entity must provide certain disclosures if “conditions or events raise substantial doubt about the entity’s ability to continue as a going concern.” The guidance is effective for annual periods ending after December 15, 2016, and interim periods thereafter, with early adoption permitted. The Company is currently evaluating the effect the guidance will have on its related disclosures. In February 2015, the FASB issued ASU 2015-02, "Amendments to the Consolidation Analysis," which makes changes to both the variable interest model and the voting model, affecting all reporting entities involved with limited partnerships or similar entities, particularly industries such as the oil and gas, transportation and real estate sectors. In addition to reducing the number of consolidation models from four to two, the guidance simplifies and improves current guidance by placing more emphasis on risk of loss when determining a controlling financial interest and reducing the frequency of the application of related-party guidance when determining a controlling financial interest in a VIE. The requirements of the guidance are effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with early adoption permitted. The Company is currently evaluating the effect, if any, that the updated standard will have on its consolidated financial statements and related disclosures. In April 2015, the FASB issued ASU 2015-03, "Simplifying the Presentation of Debt Issuance Costs", which requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability, consistent with the presentation of a debt discount. The guidance is effective on a retrospective basis for annual periods beginning after December 15, 2015, including interim periods within that reporting period, with early adoption permitted. Adoption of the guidance will result in a decrease to the Company's assets and liabilities in the consolidated balance sheets, with no impact to the consolidated statements of operations.
Fair Value Transfer	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.

Divestitures (Tables)

Divestitures (Tables)	6 Months Ended
	Jun. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
Disposal, Revenue and Expense Information	The following table presents revenues and expenses, including direct operating expenses, depletion, accretion of asset retirement obligations and general and administrative expenses, for the Gulf Properties included in the accompanying unaudited condensed consolidated statement of operations for the six -month period ended June 30, 2014 (in thousands): Six Months Ended June 30, 2014 (1) Revenues $ 90,920 Expenses $ 63,674 ____________________ (1) Includes revenues and expenses through February 25, 2014 , the date of the sale.

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	6 Months Ended
	Jun. 30, 2015
Variable Interest Entity
Royalty Trusts Distributions	The following distributions are expected to be paid on or before August 28, 2015 to holders of record as of the close of business on August 14, 2015 (in thousands): Royalty Trust Total Distribution Amount Distributed to Third-Party Unitholders Mississippian Trust I $ 8,428 $ 6,162 Permian Trust 16,656 16,656 Mississippian Trust II 9,361 7,794 Total $ 34,445 $ 30,612
Open Oil and Natural Gas Commodity Derivative Contracts	At June 30, 2015 , the Company’s open commodity derivative contracts consisted of the following: Oil Price Swaps Notional (MBbls) Weighted Average Fixed Price July 2015 - December 2015 1,570 $ 93.02 January 2016 - December 2016 1,464 $ 88.36 Natural Gas Price Swaps Notional (MMcf) Weighted Average Fixed Price July 2015 - December 2015 3,680 $ 4.20 Natural Gas Basis Swaps Notional (MMcf) Weighted Average Fixed Price July 2015 - December 2015 31,280 $ (0.30 ) January 2016 - December 2016 10,980 $ (0.38 ) Oil Collars - Three-way Notional (MBbls) Sold Put Purchased Put Sold Call July 2015 - December 2015 3,128 $78.15 $90.03 $103.65 January 2016 - December 2016 2,556 $83.14 $90.00 $100.85 Natural Gas Collars Notional (MMcf) Collar Range July 2015 - December 2015 509 $4.00 — $8.55
Royalty Trusts
Variable Interest Entity
Royalty Trust Units	Common and subordinated units outstanding as of June 30, 2015 for each Royalty Trust are as follows: Mississippian Trust I Permian Trust Mississippian Trust II Total outstanding common units(1) 28,000,000 39,375,000 37,293,750 Total outstanding subordinated units(2) — 13,125,000 12,431,250 ____________________ (1) The Mississippian Trust I’s previously outstanding subordinated units, all of which were held by SandRidge, converted to common units in the third quarter of 2014. (2) All outstanding subordinated units are owned by SandRidge.
Royalty Trusts Ownership Interest	The Company’s beneficial interests in the Royalty Trusts at June 30, 2015 and December 31, 2014 were as follows: June 30, December 31, Mississippian Trust I 26.9 % 26.9 % Permian Trust 25.0 % 25.0 % Mississippian Trust II 37.6 % 37.6 %
Royalty Trusts Distributions	Quarterly distributions declared and paid by the Royalty Trusts during the three and six -month periods ended June 30, 2015 and 2014 were as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015(1) 2014(2) 2015(1) 2014(2) Total distributions $ 47,296 $ 59,672 $ 97,499 $ 127,985 Distributions to third-party unitholders $ 40,975 $ 50,024 $ 84,690 $ 103,142 ____________________ (1) Subordination thresholds were not met for the Permian Trust and Mississippian Trust II’s distributions for the three and six -month periods ended June 30, 2015 , resulting in reduced distributions to the Company on its subordinated units for these periods. (2) Subordination thresholds were not met for the Mississippian Trust I’s distributions for the three and six -month periods ended June 30, 2014 and for the Mississippian Trust II’s distributions for the three-month period June 30, 2014 , resulting in reduced distributions to the Company on its subordinated units for these periods.
Open Oil and Natural Gas Commodity Derivative Contracts	The tables below present the open oil and natural gas commodity derivative contracts at June 30, 2015 underlying the derivatives agreements with the Mississippian Trust I and Mississippian Trust II. The derivatives agreement with the Permian Trust contained commodity derivative contracts that covered volumes of oil production through March 31, 2015 and is no longer in effect. The combined volume in the tables below reflects the total volume of the Royalty Trusts’ open oil and natural gas commodity derivative contracts. Oil Price Swaps Underlying the Royalty Trust Derivatives Agreements Notional (MBbls) Weighted Average Fixed Price July 2015 - December 2015 374 $ 97.09 Natural Gas Collars Underlying the Royalty Trust Derivatives Agreements Notional (MMcf) Collar Range July 2015 - December 2015 509 $ 4.00 — $ 8.55
Schedule Of Variable Interest Entities Assets and Liabilities	The Royalty Trusts’ assets and liabilities, after considering the effects of intercompany eliminations, included in the accompanying unaudited condensed consolidated balance sheets at June 30, 2015 and December 31, 2014 consisted of the following (in thousands): June 30, December 31, Cash and cash equivalents(1) $ 9,062 $ 9,387 Accounts receivable, net 8,455 17,660 Derivative contracts — 6,589 Total current assets 17,517 33,636 Investment in royalty interests(2) 1,325,942 1,325,942 Less: accumulated depletion and impairment(3) (808,890 ) (284,094 ) 517,052 1,041,848 Total assets $ 534,569 $ 1,075,484 Accounts payable and accrued expenses $ 185 $ 2,852 Total liabilities $ 185 $ 2,852 ____________________ (1) Includes $3.0 million held by the trustee at June 30, 2015 and December 31, 2014 as reserves for future general and administrative expenses. (2) Investment in royalty interests is included in oil and natural gas properties in the accompanying unaudited condensed consolidated balance sheets. (3) Includes cumulative full cost ceiling limitation impairment of $547.5 million and $42.3 million at June 30, 2015 and December 31, 2014 , respectively.
Pinon Gathering Company LLC
Variable Interest Entity
Schedule Of Amounts Due To/From Variable Interest Entities	Amounts due from and due to PGC as of June 30, 2015 and December 31, 2014 included in the accompanying unaudited condensed consolidated balance sheets are as follows (in thousands): June 30, December 31, Accounts receivable due from PGC $ 1,104 $ 1,141 Accounts payable due to PGC $ 4,011 $ 4,163

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Significant Unobservable Inputs - Guarantees	The significant unobservable input used in the fair value measurement of the Company’s financial guarantee liability at June 30, 2015 and December 31, 2014 is included in the table below (in thousands). Unobservable Input Estimated future payments for plugging and abandonment $ 372,034
Significant Unobservable Inputs - Derivative Contracts	The significant unobservable inputs and the range and weighted average of these inputs used in the fair value measurements of the Company’s natural gas basis swaps at June 30, 2015 and December 31, 2014 are included in the table below. Unobservable Input Range Weighted Average Fair Value (Price per Mcf) (In thousands) June 30, 2015 Natural gas basis differential forward curve $ (0.12 ) – $ (0.45 ) $ (0.27 ) $ (2,207 ) December 31, 2014 Natural gas basis differential forward curve $ (0.03 ) – $ (0.38 ) $ (0.29 ) $ 350
Assets and Liabilities Measured 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): June 30, 2015 Fair Value Measurements Netting(1) Assets/Liabilities at Fair Value Level 1 Level 2 Level 3 Assets Commodity derivative contracts $ — $ 146,124 $ — $ (2,079 ) $ 144,045 Investments 10,882 — — — 10,882 $ 10,882 $ 146,124 $ — $ (2,079 ) $ 154,927 Liabilities Guarantee $ — $ — $ 3,736 $ — $ 3,736 Commodity derivative contracts — — 2,207 (2,079 ) 128 $ — $ — $ 5,943 $ (2,079 ) $ 3,864 December 31, 2014 Fair Value Measurements Netting(1) Assets/Liabilities at Fair Value Level 1 Level 2 Level 3 Assets Commodity derivative contracts $ — $ 338,067 $ 350 $ — $ 338,417 Investments 11,106 — — — 11,106 $ 11,106 $ 338,067 $ 350 $ — $ 349,523 Liabilities Guarantee $ — $ — $ 5,104 $ — $ 5,104 $ — $ — $ 5,104 $ — $ 5,104 ____________________ (1) Represents the effect of netting assets and liabilities for counterparties with which the right of offset exists.
Fair Value, Reconciliation of Level 3 Fair Value Measurements for Guarantees	The table below sets forth a reconciliation of the Company’s Level 3 fair value measurements for the guarantee during the three and six -month periods ended June 30, 2015 and 2014 (in thousands): Three Months Ended June 30, Six Months Ended June 30, Level 3 Fair Value Measurements - Guarantee 2015 2014 2015 2014 Beginning balance $ 4,791 $ 9,480 $ 5,104 $ — Issuances(1) — — — 9,446 (Gain) loss on guarantee (1,055 ) 2,548 (1,368 ) 2,582 Ending balance $ 3,736 $ 12,028 $ 3,736 $ 12,028 ____________________ (1) Represents the fair value of the guarantee of certain plugging and abandonment obligations on behalf of Fieldwood as of February 25, 2014, the closing date for the sale of the Gulf Properties, for the six -month period ended June 30, 2014 .
Fair Value, Reconciliation of Level 3 Fair Value Measurements for Commodity Derivatives	The table below sets forth a reconciliation of the Company’s Level 3 fair value measurements for commodity derivative contracts during the three and six -month periods ended June 30, 2015 (in thousands): Level 3 Fair Value Measurements - Commodity Derivative Contracts Three Months Ended June 30, 2015 Six Months Ended June 30, 2015 Beginning balance $ 1,332 $ 350 Purchases — (1,847 ) Loss on derivative contracts (3,539 ) (710 ) Ending balance $ (2,207 ) $ (2,207 )
Senior Notes Carrying Amount and Fair Value Table	The estimated fair values and carrying values of the Company’s senior notes at June 30, 2015 and December 31, 2014 were as follows (in thousands): June 30, 2015 December 31, 2014 Fair Value Carrying Value Fair Value Carrying Value 8.75% Senior Secured Notes due 2020 $ 1,134,375 $ 1,250,000 $ — $ — Senior Unsecured Notes 8.75% Senior Notes due 2020(1) $ 243,000 $ 445,758 $ 303,750 $ 445,402 7.5% Senior Notes due 2021(2) $ 514,063 $ 1,149,175 $ 752,000 $ 1,178,486 8.125% Senior Notes due 2022 $ 320,625 $ 729,000 $ 472,500 $ 750,000 7.5% Senior Notes due 2023(3) $ 348,728 $ 821,706 $ 519,750 $ 821,548 ____________________ (1) Carrying value is net of $4,242 and $4,598 discount at June 30, 2015 and December 31, 2014 , respectively. (2) Carrying value includes a premium of $3,175 and $3,486 at June 30, 2015 and December 31, 2014 , respectively. (3) Carrying value is net of $3,294 and $3,452 discount at June 30, 2015 and December 31, 2014 , respectively.

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	6 Months Ended
	Jun. 30, 2015
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment consists of the following (in thousands): June 30, December 31, Oil and natural gas properties Proved(1) $ 12,199,049 $ 11,707,147 Unproved 261,657 290,596 Total oil and natural gas properties 12,460,706 11,997,743 Less accumulated depreciation, depletion and impairment (9,131,153 ) (6,359,149 ) Net oil and natural gas properties capitalized costs 3,329,553 5,638,594 Land 14,648 16,300 Non-oil and natural gas equipment(2) 482,923 602,392 Buildings and structures(3) 271,367 263,191 Total 768,938 881,883 Less accumulated depreciation and amortization (212,090 ) (305,420 ) Other property, plant and equipment, net 556,848 576,463 Total property, plant and equipment, net $ 3,886,401 $ 6,215,057 ____________________ (1) Includes cumulative capitalized interest of approximately $45.6 million and $38.1 million at June 30, 2015 and December 31, 2014 , respectively. (2) Includes cumulative capitalized interest of approximately $4.3 million at both June 30, 2015 and December 31, 2014 . (3) Includes cumulative capitalized interest of approximately $19.2 million and $17.1 million at June 30, 2015 and December 31, 2014 , respectively.

Other Assets (Tables)

Other Assets (Tables)	6 Months Ended
	Jun. 30, 2015
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Other Assets	Other assets consist of the following (in thousands): June 30, December 31, Debt issuance costs, net of amortization $ 83,065 $ 56,445 Deferred tax asset 52,763 95,843 Investments 10,882 11,106 Other 632 1,853 Total other assets $ 147,342 $ 165,247

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
Long-Term Debt	Long-term debt consists of the following (in thousands): June 30, December 31, Senior credit facility $ — $ — 8.75% Senior Secured Notes due 2020 1,250,000 — Senior Unsecured Notes 8.75% Senior Notes due 2020, net of $4,242 and $4,598 discount, respectively 445,758 445,402 7.5% Senior Notes due 2021, including premium of $3,175 and $3,486, respectively 1,149,175 1,178,486 8.125% Senior Notes due 2022 729,000 750,000 7.5% Senior Notes due 2023, net of $3,294 and $3,452 discount, respectively 821,706 821,548 Total debt 4,395,639 3,195,436 Less: current maturities of long-term debt — — Long-term debt $ 4,395,639 $ 3,195,436

Derivatives (Tables)

Derivatives (Tables)	6 Months Ended
	Jun. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Fair Value of Derivatives	The following table presents the fair value of the Company’s derivative contracts as of June 30, 2015 and December 31, 2014 on a gross basis without regard to same-counterparty netting (in thousands): Type of Contract Balance Sheet Classification June 30, December 31, Derivative assets Oil price swaps Derivative contracts-current $ 70,528 $ 204,072 Natural gas price swaps Derivative contracts-current 4,757 29,648 Natural gas basis swaps Derivative contracts-current — 350 Oil collars - three way Derivative contracts-current 46,825 56,289 Natural gas collars Derivative contracts-current 562 1,055 Oil price swaps Derivative contracts-noncurrent 18,867 36,288 Oil collars - three way Derivative contracts-noncurrent 4,585 10,715 Derivative liabilities Natural gas basis swaps Derivative contracts-current (2,199 ) — Natural gas basis swaps Derivative contracts-noncurrent (8 ) — Total net derivative contracts $ 143,917 $ 338,417
Offsetting Assets and Liabilities	The following tables summarize (i) the Company's derivative contracts on a gross basis, (ii) the effects of netting assets and liabilities for which the right of offset exists based on master netting arrangements and (iii) for the Company’s net derivative liability positions, the applicable portion of shared collateral under the senior credit facility (in thousands): June 30, 2015 Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount Assets Derivative contracts - current $ 122,672 $ (2,097 ) $ 120,575 $ — $ 120,575 Derivative contracts - noncurrent 23,452 18 23,470 — 23,470 Total $ 146,124 $ (2,079 ) $ 144,045 $ — $ 144,045 Liabilities Derivative contracts - current $ 2,199 $ (2,097 ) $ 102 $ (102 ) $ — Derivative contracts - noncurrent 8 18 26 (26 ) — Total $ 2,207 $ (2,079 ) $ 128 $ (128 ) $ — December 31, 2014 Gross Amounts Gross Amounts Offset Amounts Net of Offset Financial Collateral Net Amount Assets Derivative contracts - current $ 291,414 $ — $ 291,414 $ — $ 291,414 Derivative contracts - noncurrent 47,003 — 47,003 — 47,003 Total $ 338,417 $ — $ 338,417 $ — $ 338,417 Liabilities Derivative contracts - current $ — $ — $ — $ — $ — Derivative contracts - noncurrent — — — — — Total $ — $ — $ — $ — $ —
Open Oil and Natural Gas Commodity Derivative Contracts	At June 30, 2015 , the Company’s open commodity derivative contracts consisted of the following: Oil Price Swaps Notional (MBbls) Weighted Average Fixed Price July 2015 - December 2015 1,570 $ 93.02 January 2016 - December 2016 1,464 $ 88.36 Natural Gas Price Swaps Notional (MMcf) Weighted Average Fixed Price July 2015 - December 2015 3,680 $ 4.20 Natural Gas Basis Swaps Notional (MMcf) Weighted Average Fixed Price July 2015 - December 2015 31,280 $ (0.30 ) January 2016 - December 2016 10,980 $ (0.38 ) Oil Collars - Three-way Notional (MBbls) Sold Put Purchased Put Sold Call July 2015 - December 2015 3,128 $78.15 $90.03 $103.65 January 2016 - December 2016 2,556 $83.14 $90.00 $100.85 Natural Gas Collars Notional (MMcf) Collar Range July 2015 - December 2015 509 $4.00 — $8.55

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2015
Asset Retirement Obligation Disclosure [Abstract]
Reconciliation of Beginning and Ending Aggregate Carrying Amounts of Asset Retirement Obligation	A reconciliation of the beginning and ending aggregate carrying amounts of the asset retirement obligations for the period from December 31, 2014 to June 30, 2015 is as follows (in thousands): Asset retirement obligations at December 31, 2014 $ 54,402 Liability incurred upon acquiring and drilling wells 860 Liability settled or disposed in current period (369 ) Accretion 2,191 Asset retirement obligations at June 30, 2015 57,084 Less: current portion — Asset retirement obligations, net of current $ 57,084

Equity (Tables)

Equity (Tables)	6 Months Ended
	Jun. 30, 2015
Equity [Abstract]
Treasury Stock	The following table shows the number of shares withheld for taxes and the associated value of those shares for the six -month periods ended June 30, 2015 and 2014 . These shares were accounted for as treasury stock when withheld and then immediately retired. Six Months Ended June 30, 2015 2014 (In thousands) Number of shares withheld for taxes 1,279 637 Value of shares withheld for taxes $ 2,093 $ 3,865

Income Taxes (Tables)

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2015
Income Tax Disclosure [Abstract]
Provision for Income Taxes	The provision for income taxes consisted of the following components for the three and six -month periods ended June 30, 2015 and 2014 (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Current Federal $ — $ — $ — $ — State 25 (1,194 ) 65 (1,067 ) 25 (1,194 ) 65 (1,067 ) Deferred Federal — — — — State — — — — — — — — Total provision 25 (1,194 ) 65 (1,067 ) Less: income tax provision attributable to noncontrolling interest 19 88 49 170 Total provision attributable to SandRidge Energy, Inc. $ 6 $ (1,282 ) $ 16 $ (1,237 )

Loss per Share (Tables)

Loss per Share (Tables)	6 Months Ended
	Jun. 30, 2015
Earnings Per Share [Abstract]
Calculation of Weighted Average Common Shares Outstanding used in Computation of Diluted Loss Per Share	The following table summarizes the calculation of weighted average common shares outstanding used in the computation of diluted loss per share, for the three and six -month periods ended June 30, 2015 and 2014 : Net Loss Weighted Average Shares Loss Per Share (In thousands, except per share amounts) Three Months Ended June 30, 2015 Basic loss per share $ (1,375,556 ) 495,153 $ (2.78 ) Effect of dilutive securities Restricted stock and units(1) — — Convertible preferred stock(2) — — Diluted loss per share $ (1,375,556 ) 495,153 $ (2.78 ) Three Months Ended June 30, 2014 Basic loss per share $ (46,775 ) $ 485,318 $ (0.10 ) Effect of dilutive securities Restricted stock(3) — — Convertible preferred stock(4) — — Diluted loss per share $ (46,775 ) 485,318 $ (0.10 ) Six Months Ended June 30, 2015 Basic loss per share $ (2,421,390 ) 486,704 $ (4.98 ) Effect of dilutive securities Restricted stock and units(1) — — Convertible preferred stock(2) — — Diluted loss per share $ (2,421,390 ) 486,704 $ (4.98 ) Six Months Ended June 30, 2014 Basic loss per share $ (196,993 ) 485,059 $ (0.41 ) Effect of dilutive securities Restricted stock(3) — — Convertible preferred stock(4) — — Diluted loss per share $ (196,993 ) 485,059 $ (0.41 ) ____________________ (1) No incremental shares of potentially dilutive restricted stock awards or units were included for the three and six -month periods ended June 30, 2015 as their effect was antidilutive under the treasury stock method. (2) Potential common shares related to the Company’s outstanding 8.5% and 7.0% convertible perpetual preferred stock covering 71.7 million shares for the three and six -month periods ended June 30, 2015 , were excluded from the computation of loss per share because their effect would have been antidilutive under the if-converted method. (3) Restricted stock awards covering 2.0 million and 2.6 million shares for the three and six -month periods ended June 30, 2014 , respectively, were excluded from the computation of loss per share because their effect would have been antidilutive. (4) Potential common shares related to the Company’s outstanding 8.5% , 6.0% and 7.0% convertible perpetual preferred stock covering 90.1 million shares for the three and six -month periods ended June 30, 2014 , were excluded from the computation of loss per share because their effect would have been antidilutive under the if-converted method.

Share-Based Compensation (Table

Share-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of Unvested Restricted Stock Awards	The following table presents a summary of the Company’s unvested restricted stock awards. Number of Shares Weighted- Average Grant Date Fair Value (In thousands) Unvested restricted shares outstanding at December 31, 2014 8,556 $ 6.39 Granted 662 $ 1.78 Vested (3,030 ) $ 6.34 Forfeited / Canceled (575 ) $ 6.39 Unvested restricted shares outstanding at June 30, 2015 5,613 $ 5.88
Summary of Unvested Restricted Stock Units	The following table presents a summary of the Company’s unvested restricted stock units which vest ratably over a four -year period from the date of grant. These restricted stock units may be settled in shares of the Company’s common stock, cash or some combination of common stock and cash at the Company’s election and were valued at June 30, 2015 based upon the Company’s period end common stock price. Number of Units Fair Value per Unit at June 30, 2015 (In thousands) Unvested units outstanding at December 31, 2014 — Granted 8,945 Vested (827 ) Forfeited / Canceled (543 ) Unvested units outstanding at June 30, 2015 7,575 $ 0.88 The following table presents a summary of the Company’s unvested restricted stock units which vest over a two -year period ( 40% at the end of the first year and 60% at the end of the second year). These restricted stock units will be settled in cash at the end of each vesting period for an amount based on the Company’s common stock price as of the vesting date. The restricted stock units were valued based upon the Company’s period end common stock price, discounted using a credit spread ( 3.6% at June 30, 2015 ) that was determined based upon an analysis of the historical option adjusted spread for the Company’s outstanding senior notes and the outstanding long-term debt of comparable companies. Number of Units Fair Value per Unit at June 30, 2015 (In thousands) Unvested units outstanding at December 31, 2014 — Granted 2,398 Vested — Forfeited / Canceled (122 ) Unvested units outstanding at June 30, 2015 2,276 $ 0.51 – $ 0.73
Performance Units/Performance Share Units Fair Value Assumptions	The following table presents a summary of the fair values of the performance share units granted and the related assumptions for all outstanding performance share units at June 30, 2015 . June 30, 2015 Expected price volatility range 29.0 % - 77.2 % Weighted-average risk-free interest rate 0.9 % Weighted-average fair value per unit $ 0.52 The following table presents a summary of the fair values of the performance units granted during the years ended December 31, 2014 and 2013 and the related assumptions for all outstanding performance units at June 30, 2015 and December 31, 2014 . June 30, 2015 December 31, 2014 Expected price volatility range 25.7 % - 89.7 % 26.6 % - 86.6 % Weighted-average risk-free interest rate 0.3 % 0.5 % Weighted-average fair value per unit $ 1.41 $ 13.85
Performance Units/Performance Share Units Outstanding Activity	P erformance share unit activity for the six-month period ended June 30, 2015 was as follows: Number of Performance Share Units (In thousands) Outstanding at December 31, 2014 — Granted 2,044 Forfeited /canceled (151 ) Outstanding at June 30, 2015 1,893 Performance period ending December 31, 2017 Vested — Unvested 1,893 Performance unit activity for the six-month period ended June 30, 2015 was as follows: Number of Performance Units (In thousands) Outstanding at December 31, 2014 66 Granted — Forfeited /canceled — Outstanding at June 30, 2015 66 Performance period ending December 31, 2015 Vested 22 Unvested 6 Performance period ending December 31, 2016 Vested 15 Unvested 23

Business Segment Information (T

Business Segment Information (Tables)	6 Months Ended
	Jun. 30, 2015
Segment Reporting [Abstract]
Summarized Financial Information Concerning Segments	Summarized financial information concerning the Company’s segments is shown in the following table (in thousands): Exploration and Production(1) Drilling and Oil Field Services(2)(3) Midstream Services All Other Consolidated Total Three Months Ended June 30, 2015 Revenues $ 214,534 $ 17,161 $ 20,782 $ 1,228 $ 253,705 Inter-segment revenue (2 ) (11,920 ) (12,176 ) — (24,098 ) Total revenues $ 214,532 $ 5,241 $ 8,606 $ 1,228 $ 229,607 Loss from operations $ (1,511,600 ) $ (3,754 ) $ (3,154 ) $ (16,575 ) $ (1,535,083 ) Interest expense (23 ) — — (73,704 ) (73,727 ) Gain on extinguishment of debt — — — 17,934 17,934 Other income, net 1,630 4 9 527 2,170 Loss before income taxes $ (1,509,993 ) $ (3,750 ) $ (3,145 ) $ (71,818 ) $ (1,588,706 ) Capital expenditures(4) $ 151,440 $ 598 $ 8,249 $ 7,279 $ 167,566 Depreciation, depletion, amortization and accretion $ 95,430 $ 5,000 $ 2,793 $ 4,694 $ 107,917 Three Months Ended June 30, 2014 Revenues $ 339,906 $ 51,891 $ 38,420 $ 1,105 $ 431,322 Inter-segment revenue — (33,062 ) (23,546 ) — (56,608 ) Total revenues $ 339,906 $ 18,829 $ 14,874 $ 1,105 $ 374,714 Income (loss) from operations $ 69,782 $ (2,347 ) $ (2,345 ) $ (23,011 ) $ 42,079 Interest expense (4 ) — — (61,859 ) (61,863 ) Other (expense) income, net (49 ) (75 ) — 1,462 1,338 Income (loss) before income taxes $ 69,729 $ (2,422 ) $ (2,345 ) $ (83,408 ) $ (18,446 ) Capital expenditures(4) $ 356,568 $ 6,654 $ 5,808 $ 7,907 $ 376,937 Depreciation, depletion, amortization and accretion $ 98,357 $ 7,661 $ 2,509 $ 5,216 $ 113,743 Six Months Ended June 30, 2015 Revenues $ 410,277 $ 41,790 $ 42,312 $ 2,195 $ 496,574 Inter-segment revenue (13 ) (26,704 ) (24,942 ) — (51,659 ) Total revenues $ 410,264 $ 15,086 $ 17,370 $ 2,195 $ 444,915 Loss from operations $ (2,565,759 ) $ (11,526 ) $ (7,027 ) $ (39,227 ) $ (2,623,539 ) Interest expense, net (40 ) — — (136,529 ) (136,569 ) Gain on extinguishment of debt — — — 17,934 17,934 Other income, net 1,176 — 13 445 1,634 Loss before income taxes $ (2,564,623 ) $ (11,526 ) $ (7,014 ) $ (157,377 ) $ (2,740,540 ) Capital expenditures(4) $ 453,503 $ 2,472 $ 16,681 $ 15,100 $ 487,756 Depreciation, depletion, amortization and accretion $ 202,640 $ 10,760 $ 5,473 $ 9,578 $ 228,451 At June 30, 2015 Total assets $ 3,708,676 $ 91,905 $ 221,064 $ 1,413,403 $ 5,435,048 Exploration and Production(1) Drilling and Oil Field Services(2)(3) Midstream Services All Other Consolidated Total Six Months Ended June 30, 2014 Revenues $ 747,244 $ 98,971 $ 84,715 $ 2,075 $ 933,005 Inter-segment revenue — (63,039 ) (52,196 ) — (115,235 ) Total revenues $ 747,244 $ 35,932 $ 32,519 $ 2,075 $ 817,770 Income (loss) from operations $ 13,306 $ (5,449 ) $ (3,756 ) $ (44,352 ) $ (40,251 ) Interest income (expense), net 139 — — (124,045 ) (123,906 ) Other (expense) income, net (234 ) (473 ) — 4,139 3,432 Income (loss) before income taxes $ 13,211 $ (5,922 ) $ (3,756 ) $ (164,258 ) $ (160,725 ) Capital expenditures(4) $ 620,809 $ 7,275 $ 11,766 $ 12,860 $ 652,710 Depreciation, depletion, amortization and accretion $ 219,398 $ 15,372 $ 4,950 $ 10,476 $ 250,196 At December 31, 2014 Total assets $ 6,273,802 $ 115,083 $ 219,691 $ 650,649 $ 7,259,225 ____________________ (1) (Loss) income from operations includes full cost ceiling limitation impairments of $1.5 billion and $2.6 billion for the three and six -month periods ended June 30, 2015 , respectively, and $164.8 million for the six -month period ended June 30, 2014 . (2) (Loss) income from operations includes an impairment of $3.1 million on certain drilling assets held for sale for the three and six -month periods ended June 30, 2014 . (3) Drilling and oilfield services assets with a net book value of approximately $20.0 million were reclassified as assets held for sale during the three-month period ended June 30, 2015 . (4) On an accrual basis and exclusive of acquisitions.

Condensed Consolidating Finan39

Condensed Consolidating Financial Information (Tables)	6 Months Ended
	Jun. 30, 2015
Condensed Consolidating Financial Statements Disclosure [Abstract]
Condensed Consolidating Balance Sheets	Condensed Consolidating Balance Sheets June 30, 2015 Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) ASSETS Current assets Cash and cash equivalents $ 970,115 $ 4,440 $ 9,062 $ — $ 983,617 Accounts receivable, net 7 228,493 9,227 (7 ) 237,720 Intercompany accounts receivable 1,026,442 1,341,801 35,566 (2,403,809 ) — Derivative contracts — 120,575 14,241 (14,241 ) 120,575 Prepaid expenses — 9,926 12 — 9,938 Other current assets — 25,985 — — 25,985 Total current assets 1,996,564 1,731,220 68,108 (2,418,057 ) 1,377,835 Property, plant and equipment, net — 3,334,417 551,984 — 3,886,401 Investment in subsidiaries 4,307,423 7,878 — (4,315,301 ) — Derivative contracts — 23,470 — — 23,470 Other assets 135,828 16,785 631 (5,902 ) 147,342 Total assets $ 6,439,815 $ 5,113,770 $ 620,723 $ (6,739,260 ) $ 5,435,048 LIABILITIES AND EQUITY Current liabilities Accounts payable and accrued expenses $ 177,231 $ 316,001 $ 1,450 $ (7 ) $ 494,675 Intercompany accounts payable 1,328,602 1,040,026 35,181 (2,403,809 ) — Derivative contracts — 14,343 — (14,241 ) 102 Deferred tax liability 52,763 — — — 52,763 Other current liabilities — 3,791 — — 3,791 Total current liabilities 1,558,596 1,374,161 36,631 (2,418,057 ) 551,331 Investment in subsidiaries 914,164 273,921 — (1,188,085 ) — Long-term debt 4,401,541 — — (5,902 ) 4,395,639 Derivative contracts — 26 — — 26 Asset retirement obligations — 57,084 — — 57,084 Other long-term obligations 77 15,319 — — 15,396 Total liabilities 6,874,378 1,720,511 36,631 (3,612,044 ) 5,019,476 Equity SandRidge Energy, Inc. stockholders’ equity (434,563 ) 3,393,259 584,092 (3,977,351 ) (434,563 ) Noncontrolling interest — — — 850,135 850,135 Total equity (434,563 ) 3,393,259 584,092 (3,127,216 ) 415,572 Total liabilities and equity $ 6,439,815 $ 5,113,770 $ 620,723 $ (6,739,260 ) $ 5,435,048 December 31, 2014 Parent Guarantors(1) Non-Guarantors(2) Eliminations(1)(2) Consolidated (In thousands) ASSETS Current assets Cash and cash equivalents $ 170,468 $ 1,398 $ 9,387 $ — $ 181,253 Accounts receivable, net 7 299,764 30,313 (7 ) 330,077 Intercompany accounts receivable 751,376 1,339,152 41,679 (2,132,207 ) — Derivative contracts — 284,825 45,043 (38,454 ) 291,414 Prepaid expenses — 7,971 10 — 7,981 Other current assets — 21,193 — — 21,193 Total current assets 921,851 1,954,303 126,432 (2,170,668 ) 831,918 Property, plant and equipment, net — 5,137,702 1,077,355 — 6,215,057 Investment in subsidiaries 6,606,198 25,944 — (6,632,142 ) — Derivative contracts — 47,003 — — 47,003 Other assets 152,286 18,197 666 (5,902 ) 165,247 Total assets $ 7,680,335 $ 7,183,149 $ 1,204,453 $ (8,808,712 ) $ 7,259,225 LIABILITIES AND EQUITY Current liabilities Accounts payable and accrued expenses $ 201,368 $ 477,399 $ 4,632 $ (7 ) $ 683,392 Intercompany accounts payable 1,315,667 780,645 35,895 (2,132,207 ) — Derivative contracts — 38,454 — (38,454 ) — Deferred tax liability 95,843 — — — 95,843 Other current liabilities — 5,216 — — 5,216 Total current liabilities 1,612,878 1,301,714 40,527 (2,170,668 ) 784,451 Investment in subsidiaries 928,217 134,013 — (1,062,230 ) — Long-term debt 3,201,338 — — (5,902 ) 3,195,436 Asset retirement obligations — 54,402 — — 54,402 Other long-term obligations 77 15,039 — — 15,116 Total liabilities 5,742,510 1,505,168 40,527 (3,238,800 ) 4,049,405 Equity SandRidge Energy, Inc. stockholders’ equity 1,937,825 5,677,981 1,163,926 (6,841,907 ) 1,937,825 Noncontrolling interest — — — 1,271,995 1,271,995 Total equity 1,937,825 5,677,981 1,163,926 (5,569,912 ) 3,209,820 Total liabilities and equity $ 7,680,335 $ 7,183,149 $ 1,204,453 $ (8,808,712 ) $ 7,259,225 ____________________ (1) Amounts presented as property, plant and equipment have been revised to include approximately $150.4 million previously misclassified as investment in subsidiary. (2) Amounts previously misclassified as property, plant and equipment and SandRidge Energy, Inc. stockholders’ equity have been reduced by approximately $150.4 million and are now presented as Guarantor property, plant and equipment.
Condensed Consolidating Statements of Operations	Condensed Consolidating Statements of Operations Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Three Months Ended June 30, 2015 Total revenues $ — $ 203,591 $ 26,016 $ — $ 229,607 Expenses Direct operating expenses — 95,832 2,934 — 98,766 General and administrative 61 37,379 942 — 38,382 Depreciation, depletion, amortization and accretion — 98,416 9,501 — 107,917 Impairment — 1,164,834 324,557 — 1,489,391 Loss on derivative contracts — 29,067 3,937 — 33,004 Gain on sale of assets — (2,770 ) — — (2,770 ) Total expenses 61 1,422,758 341,871 — 1,764,690 (Loss) from operations (61 ) (1,219,167 ) (315,855 ) — (1,535,083 ) Equity earnings from subsidiaries (1,312,652 ) (95,545 ) — 1,408,197 — Interest expense (73,703 ) (24 ) — — (73,727 ) Gain on extinguishment of debt 17,934 — — — 17,934 Other income, net — 2,084 86 — 2,170 Loss before income taxes (1,368,482 ) (1,312,652 ) (315,769 ) 1,408,197 (1,588,706 ) Income tax expense — — 25 — 25 Net loss (1,368,482 ) (1,312,652 ) (315,794 ) 1,408,197 (1,588,731 ) Less: net loss attributable to noncontrolling interest — — — (220,249 ) (220,249 ) Net loss attributable to SandRidge Energy, Inc. $ (1,368,482 ) $ (1,312,652 ) $ (315,794 ) $ 1,628,446 $ (1,368,482 ) Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Three Months Ended June 30, 2014 Total revenues $ — $ 314,521 $ 60,205 $ (12 ) $ 374,714 Expenses Direct operating expenses — 93,597 4,931 (12 ) 98,516 General and administrative 71 30,481 1,363 — 31,915 Depreciation, depletion, amortization and accretion — 99,237 14,506 — 113,743 Impairment — 3,133 — — 3,133 Loss on derivative contracts — 67,509 17,783 — 85,292 Loss on sale of assets — 36 — — 36 Total expenses 71 293,993 38,583 (12 ) 332,635 (Loss) income from operations (71 ) 20,528 21,622 — 42,079 Equity earnings from subsidiaries 27,725 5,863 — (33,588 ) — Interest expense (61,859 ) (4 ) — — (61,863 ) Other income, net — 1,338 — — 1,338 (Loss) income before income taxes (34,205 ) 27,725 21,622 (33,588 ) (18,446 ) Income tax (benefit) expense (1,311 ) — 117 — (1,194 ) Net (loss) income (32,894 ) 27,725 21,505 (33,588 ) (17,252 ) Less: net income attributable to noncontrolling interest — — — 15,642 15,642 Net (loss) income attributable to SandRidge Energy, Inc. $ (32,894 ) $ 27,725 $ 21,505 $ (49,230 ) $ (32,894 ) Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Six Months Ended June 30, 2015 Total revenues $ — $ 396,112 $ 48,811 $ (8 ) $ 444,915 Expenses Direct operating expenses — 207,950 5,770 (8 ) 213,712 General and administrative 117 72,598 1,816 — 74,531 Depreciation, depletion, amortization and accretion — 208,269 20,182 — 228,451 Impairment — 2,068,069 505,188 — 2,573,257 Gain on derivative contracts — (15,042 ) (1,781 ) — (16,823 ) Gain on sale of assets — (4,670 ) (4 ) — (4,674 ) Total expenses 117 2,537,174 531,171 (8 ) 3,068,454 Loss from operations (117 ) (2,141,062 ) (482,360 ) — (2,623,539 ) Equity earnings from subsidiaries (2,284,723 ) (145,166 ) — 2,429,889 — Interest expense (136,529 ) (40 ) — — (136,569 ) Gain on extinguishment of debt 17,934 — — — 17,934 Other income, net — 1,545 89 — 1,634 Loss before income taxes (2,403,435 ) (2,284,723 ) (482,271 ) 2,429,889 (2,740,540 ) Income tax expense — — 65 — 65 Net loss (2,403,435 ) (2,284,723 ) (482,336 ) 2,429,889 (2,740,605 ) Less: net loss attributable to noncontrolling interest — — — (337,170 ) (337,170 ) Net loss attributable to SandRidge Energy, Inc. $ (2,403,435 ) $ (2,284,723 ) $ (482,336 ) $ 2,767,059 $ (2,403,435 ) Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Six Months Ended June 30, 2014 Total revenues $ — $ 693,570 $ 124,299 $ (99 ) $ 817,770 Expenses Direct operating expenses — 232,018 9,741 (99 ) 241,660 General and administrative 220 67,426 2,807 — 70,453 Depreciation, depletion, amortization and accretion — 219,814 30,382 — 250,196 Impairment — 125,599 42,313 — 167,912 Loss on derivative contracts — 101,611 26,172 — 127,783 Loss on sale of assets — 17 — — 17 Total expenses 220 746,485 111,415 (99 ) 858,021 (Loss) income from operations (220 ) (52,915 ) 12,884 — (40,251 ) Equity earnings from subsidiaries (46,259 ) 3,086 — 43,173 — Interest (expense) income (124,045 ) 139 — — (123,906 ) Other income, net — 3,431 1 — 3,432 (Loss) income before income taxes (170,524 ) (46,259 ) 12,885 43,173 (160,725 ) Income tax (benefit) expense (1,294 ) — 227 — (1,067 ) Net (loss) income (169,230 ) (46,259 ) 12,658 43,173 (159,658 ) Less: net income attributable to noncontrolling interest — — — 9,572 9,572 Net (loss) income attributable to SandRidge Energy, Inc. $ (169,230 ) $ (46,259 ) $ 12,658 $ 33,601 $ (169,230 )
Condensed Consolidating Statements of Cash Flows	Condensed Consolidating Statements of Cash Flows Parent Guarantors Non-Guarantors Eliminations Consolidated (In thousands) Six Months Ended June 30, 2015 Net cash (used in) provided by operating activities $ (122,181 ) $ 344,778 $ 65,902 $ 30,495 $ 318,994 Cash flows from investing activities Capital expenditures for property, plant, and equipment — (636,822 ) — — (636,822 ) Other — (65,989 ) 5 73,971 7,987 Net cash (used in) provided by investing activities — (702,811 ) 5 73,971 (628,835 ) Cash flows from financing activities Proceeds from borrowings 2,190,000 — — — 2,190,000 Repayments of borrowings (940,000 ) — — — (940,000 ) Distributions to unitholders — — (97,498 ) 12,808 (84,690 ) Intercompany (advances) borrowings, net (275,066 ) 276,384 (1,318 ) — — Other (53,106 ) 84,691 32,584 (117,274 ) (53,105 ) Net cash provided by (used in) financing activities 921,828 361,075 (66,232 ) (104,466 ) 1,112,205 Net increase (decrease) in cash and cash equivalents 799,647 3,042 (325 ) — 802,364 Cash and cash equivalents at beginning of year 170,468 1,398 9,387 — 181,253 Cash and cash equivalents at end of period $ 970,115 $ 4,440 $ 9,062 $ — $ 983,617 Parent(1) Guarantors(1) Non-Guarantors Eliminations Consolidated (In thousands) Six Months Ended June 30, 2014 Net cash (used in) provided by operating activities $ (119,006 ) $ 228,860 $ 126,424 $ (5,486 ) $ 230,792 Cash flows from investing activities Capital expenditures for property, plant, and equipment — (656,699 ) — — (656,699 ) Proceeds from sale of assets — 707,799 — — 707,799 Other — (104,286 ) 1,061 86,672 (16,553 ) Net cash (used in) provided by investing activities — (53,186 ) 1,061 86,672 34,547 Cash flows from financing activities Distributions to unitholders — — (127,985 ) 24,843 (103,142 ) Intercompany borrowings (advances), net 257,498 (257,879 ) 381 — — Other (33,364 ) 82,441 (1,150 ) (106,029 ) (58,102 ) Net cash provided by (used in) financing activities 224,134 (175,438 ) (128,754 ) (81,186 ) (161,244 ) Net increase (decrease) in cash and cash equivalents 105,128 236 (1,269 ) — 104,095 Cash and cash equivalents at beginning of year 805,505 1,013 8,145 — 814,663 Cash and cash equivalents at end of period $ 910,633 $ 1,249 $ 6,876 $ — $ 918,758 ____________________ (1) Net cash (used in) provided by operating activities for the Parent has been corrected to exclude $382.7 million in intercompany transactions, and a corresponding increase for Guarantors for this same line item. In addition, Intercompany borrowings (advances), net has been corrected for the Parent to include approximately $382.7 million of intercompany transactions, and a corresponding decrease for Guarantors for the same line item. The changes did not result in any changes to consolidated net cash provided by operating activities or net cash used in financing activities.

Subsequent Events (Tables)

Subsequent Events (Tables)	6 Months Ended
	Jun. 30, 2015
Subsequent Events [Abstract]
Royalty Trust Distributions	The following distributions are expected to be paid on or before August 28, 2015 to holders of record as of the close of business on August 14, 2015 (in thousands): Royalty Trust Total Distribution Amount Distributed to Third-Party Unitholders Mississippian Trust I $ 8,428 $ 6,162 Permian Trust 16,656 16,656 Mississippian Trust II 9,361 7,794 Total $ 34,445 $ 30,612

Divestitures - Gulf Properties

Divestitures - Gulf Properties Disposal - Revenue and Expense Information (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Disposal, Revenue and Expense Information
Revenues	$ 229,607	$ 374,714	$ 444,915	$ 817,770
Expenses	$ 1,764,690	$ 332,635	$ 3,068,454	858,021
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Gulf Properties
Disposal, Revenue and Expense Information
Revenues				90,920
Expenses				$ 63,674

Divestitures - Narrative (Detai

Divestitures - Narrative (Details) - Disposal Group, Disposed of by Sale, Not Discontinued Operations - Gulf Properties - USD ($)	Feb. 25, 2014	Jun. 30, 2015	Dec. 31, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and natural gas properties	$ 702,600,000
Gain (loss) on sale of oil and gas property	$ 0
Contingent consideration liability, guarantee period	1 year
Contingent consideration, liability	$ 9,400,000	$ 3,700,000	$ 5,100,000
Restricted deposits previously held in escrow, cash received		$ 12,000,000
Asset Retirement Obligations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Asset retirement obligations assumed	$ 366,000,000

Variable Interest Entities - Ro

Variable Interest Entities - Royalty Trusts - Common and Subordinated Units Outstanding (Details)	6 Months Ended
	Jun. 30, 2015shares
Mississippian Trust I
Variable Interest Entity
Total outstanding common units (in shares)	28,000,000
Total outstanding subordinated units (in shares)	0
Permian Trust
Variable Interest Entity
Total outstanding common units (in shares)	39,375,000
Total outstanding subordinated units (in shares)	13,125,000
Mississippian Trust II
Variable Interest Entity
Total outstanding common units (in shares)	37,293,750
Total outstanding subordinated units (in shares)	12,431,250

Variable Interest Entities - 44

Variable Interest Entities - Royalty Trusts - Ownership Interest (Details)	Jun. 30, 2015	Dec. 31, 2014
Mississippian Trust I
Variable Interest Entity
Beneficial interest owned by Company	26.90%	26.90%
Permian Trust
Variable Interest Entity
Beneficial interest owned by Company	25.00%	25.00%
Mississippian Trust II
Variable Interest Entity
Beneficial interest owned by Company	37.60%	37.60%

Variable Interest Entities - 45

Variable Interest Entities - Royalty Trusts - Distributions (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Variable Interest Entity
Distributions to third-party unitholders			$ 84,690	$ 103,142
Royalty Trusts
Variable Interest Entity
Total distributions	$ 47,296	$ 59,672	97,499	127,985
Distributions to third-party unitholders	$ 40,975	$ 50,024	$ 84,690	$ 103,142

Variable Interest Entities - 46

Variable Interest Entities - Royalty Trusts - Open Oil and Natural Gas Commodity Derivative Contracts (Details) - Jun. 30, 2015 - July 2015 - December 2015	$ / Mcf$ / bblMBblsMMcf
Oil Price Swaps
Derivative Instruments and Hedging Activities Disclosure
Notional (Oil in MBbls/Natural Gas in MMcf) | MBbls	1,570
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / bbl	93.02
Natural Gas Collars
Derivative Instruments and Hedging Activities Disclosure
Notional (Oil in MBbls/Natural Gas in MMcf) | MMcf	509
Collar Range, minimum	4
Collar Range, maximum	8.55
Royalty Trusts | Oil Price Swaps
Derivative Instruments and Hedging Activities Disclosure
Notional (Oil in MBbls/Natural Gas in MMcf) | MBbls	374
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / bbl	97.09
Royalty Trusts | Natural Gas Collars
Derivative Instruments and Hedging Activities Disclosure
Notional (Oil in MBbls/Natural Gas in MMcf) | MMcf	509
Collar Range, minimum	4
Collar Range, maximum	8.55

Variable Interest Entities - 47

Variable Interest Entities - Royalty Trusts - Assets and Liabilities Included in Unaudited Condensed Consolidated Balance Sheets (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014	Jun. 30, 2014	Dec. 31, 2013
Variable Interest Entity
Cash and cash equivalents	$ 983,617	$ 181,253	$ 918,758	$ 814,663
Accounts receivable, net	237,720	330,077
Derivative contracts	120,575	291,414
Total current assets	1,377,835	831,918
Investment in royalty interests	12,460,706	11,997,743
Less: accumulated depletion and impairment	(9,131,153)	(6,359,149)
Net oil and natural gas properties capitalized costs	3,329,553	5,638,594
Accounts payable and accrued expenses	494,675	683,392
Royalty Trusts
Variable Interest Entity
Cash and cash equivalents	9,062	9,387
Accounts receivable, net	8,455	17,660
Derivative contracts	0	6,589
Total current assets	17,517	33,636
Investment in royalty interests	1,325,942	1,325,942
Less: accumulated depletion and impairment	(808,890)	(284,094)
Net oil and natural gas properties capitalized costs	517,052	1,041,848
Total assets	534,569	1,075,484
Accounts payable and accrued expenses	185	2,852
Total liabilities	$ 185	$ 2,852

Variable Interest Entities - 48

Variable Interest Entities - Royalty Trusts - Assets and Liabilities Included in Unaudited Condensed Consolidated Balance Sheets (Additional Information) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Variable Interest Entity
Cumulative full cost ceiling limitation impairment	$ 6,300	$ 3,700
Royalty Trusts
Variable Interest Entity
Reserves for expenses	3	3
Cumulative full cost ceiling limitation impairment	$ 547.5	$ 42.3

Variable Interest Entities - PG

Variable Interest Entities - PGC - Amounts due to/from the Company (Details) - Pinon Gathering Company LLC - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Variable Interest Entity
Accounts receivable due from PGC	$ 1,104	$ 1,141
Accounts payable due to PGC	$ 4,011	$ 4,163

Variable Interest Entities - Na

Variable Interest Entities - Narrative (Details) - USD ($)	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Mar. 31, 2014	Dec. 31, 2013
Variable Interest Entity
Proceeds from sale of royalty trust units	$ 0	$ 22,119,000
Royalty Trusts
Variable Interest Entity
Percentage of royalty interest conveyed to company at trust termination	50.00%
Percentage of royalty interest sold at trust termination	50.00%
Percentage of subordinated units to total units	25.00%
Percentage of cash available in excess of target distribution paid for incentive distribution	50.00%
Outstanding balance under loan commitment	$ 0		$ 0
Noncontrolling interest	$ 850,200,000		$ 1,300,000,000
Proceeds from sale of royalty trust units		$ 22,100,000
Grey Ranch Plant, L.P
Variable Interest Entity
Beneficial interest owned by Company					50.00%
Company purchase of noncontrolling interest, percentage				50.00%
Grey Ranch Plant Genpar, LLC ("Genpar")
Variable Interest Entity
Beneficial interest owned by Company					50.00%
Company purchase of noncontrolling interest, percentage				50.00%
Percentage ownership of another VIE					1.00%

Fair Value Measurements - Signi

Fair Value Measurements - Significant Unobservable Inputs - Guarantees (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Gulf Properties | Fair Value Measurements Level 3
Significant Unobservable Inputs
Estimated future payments for plugging and abandonment	$ 372,034	$ 372,034

Fair Value Measurements - Sig52

Fair Value Measurements - Significant Unobservable Inputs - Derivative Contracts (Details) - Fair Value Measurements Level 3 - Natural Gas Basis Swaps $ in Thousands	Jun. 30, 2015USD ($)$ / Mcf	Dec. 31, 2014USD ($)$ / Mcf
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation
Derivative, weighted average forward price (usd/mcf)	(0.27)	(0.29)
Fair value, level 3 commodity derivative contracts | $	$ (2,207)	$ 350
Minimum
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation
Derivative, forward price (usd/mcf)	(0.12)	(0.03)
Maximum
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation
Derivative, forward price (usd/mcf)	(0.45)	(0.38)

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring Basis
Commodity derivative contracts, assets, net of offset	$ 144,045	$ 338,417
Commodity derivative contracts, liabilities, net of offset	128	0
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring Basis
Netting adjustment, assets	(2,079)	0
Commodity derivative contracts, assets, net of offset	144,045	338,417
Investments	10,882	11,106
Assets measured at fair value	154,927	349,523
Guarantee	3,736	5,104
Netting adjustments, liabilities	(2,079)	0
Commodity derivative contracts, liabilities, net of offset	128
Liabilities measured at fair value	3,864	5,104
Fair Value, Measurements, Recurring | Fair Value Measurements Level 1
Fair Value, Assets and Liabilities Measured on Recurring Basis
Commodity derivative contracts, assets, before netting	0	0
Investments	10,882	11,106
Assets measured at fair value	10,882	11,106
Guarantee	0	0
Commodity derivative contracts, liabilities, before netting	0
Liabilities measured at fair value	0	0
Fair Value, Measurements, Recurring | Fair Value Measurements Level 2
Fair Value, Assets and Liabilities Measured on Recurring Basis
Commodity derivative contracts, assets, before netting	146,124	338,067
Investments	0	0
Assets measured at fair value	146,124	338,067
Guarantee	0	0
Commodity derivative contracts, liabilities, before netting	0
Liabilities measured at fair value	0	0
Fair Value, Measurements, Recurring | Fair Value Measurements Level 3
Fair Value, Assets and Liabilities Measured on Recurring Basis
Commodity derivative contracts, assets, before netting	0	350
Investments	0	0
Assets measured at fair value	0	350
Guarantee	3,736	5,104
Commodity derivative contracts, liabilities, before netting	2,207
Liabilities measured at fair value	$ 5,943	$ 5,104

Fair Value Measurements - Recon

Fair Value Measurements - Reconciliation of Fair Value Measurements for Guarantees (Details) - Guarantees - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Level 3 Fair Value Measurements - Guarantee
Beginning balance	$ 4,791	$ 9,480	$ 5,104	$ 0
Issuances	0	0	0	9,446
(Gain) loss on guarantee	(1,055)	2,548	(1,368)	2,582
Ending balance	$ 3,736	$ 12,028	$ 3,736	$ 12,028

Fair Value Measurements - Rec55

Fair Value Measurements - Reconciliation of Fair Value Measurements for Commodity Derivative Contracts (Details) - Jun. 30, 2015 - Commodity derivative contracts - USD ($) $ in Thousands	Total	Total
Level 3 Fair Value Measurements - Commodity Derivative Contracts
Beginning balance	$ 1,332	$ 350
Purchases	0	(1,847)
Loss on derivative contracts	(3,539)	(710)
Ending balance	$ (2,207)	$ (2,207)

Fair Value Measurements - Estim

Fair Value Measurements - Estimated Fair Value and Carrying Value of Senior Notes (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring Basis
Carrying Value	$ 4,395,639	$ 3,195,436
8.75% Senior Secured Notes due 2020
Fair Value, Assets and Liabilities Measured on Recurring Basis
Carrying Value	1,250,000	0
8.75% Senior Notes due 2020
Fair Value, Assets and Liabilities Measured on Recurring Basis
Carrying Value	445,758	445,402
7.5% Senior Notes due 2021
Fair Value, Assets and Liabilities Measured on Recurring Basis
Carrying Value	1,149,175	1,178,486
8.125% Senior Notes due 2022
Fair Value, Assets and Liabilities Measured on Recurring Basis
Carrying Value	729,000	750,000
7.5% Senior Notes due 2023
Fair Value, Assets and Liabilities Measured on Recurring Basis
Carrying Value	821,706	821,548
Fair Value Measurements Level 2 | 8.75% Senior Secured Notes due 2020
Fair Value, Assets and Liabilities Measured on Recurring Basis
Fair Value	1,134,375	0
Fair Value Measurements Level 2 | 8.75% Senior Notes due 2020
Fair Value, Assets and Liabilities Measured on Recurring Basis
Fair Value	243,000	303,750
Fair Value Measurements Level 2 | 7.5% Senior Notes due 2021
Fair Value, Assets and Liabilities Measured on Recurring Basis
Fair Value	514,063	752,000
Fair Value Measurements Level 2 | 8.125% Senior Notes due 2022
Fair Value, Assets and Liabilities Measured on Recurring Basis
Fair Value	320,625	472,500
Fair Value Measurements Level 2 | 7.5% Senior Notes due 2023
Fair Value, Assets and Liabilities Measured on Recurring Basis
Fair Value	$ 348,728	$ 519,750

Fair Value Measurements - Est57

Fair Value Measurements - Estimated Fair Value and Carrying Value of Senior Notes (Additional Information) (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
8.75% Senior Notes due 2020
Fair Value, Assets and Liabilities Measured on Recurring Basis
Long-term debt, discount	$ 4,242	$ 4,598
7.5% Senior Notes due 2021
Fair Value, Assets and Liabilities Measured on Recurring Basis
Long term debt, premium	3,175	3,486
7.5% Senior Notes due 2023
Fair Value, Assets and Liabilities Measured on Recurring Basis
Long-term debt, discount	$ 3,294	$ 3,452
Senior Notes | 8.75% Senior Notes due 2020
Fair Value, Assets and Liabilities Measured on Recurring Basis
Long-term debt, fixed interest rate	8.75%	8.75%
Debt maturity date	2,020	2,020
Long-term debt, discount	$ 4,242	$ 4,598
Senior Notes | 7.5% Senior Notes due 2021
Fair Value, Assets and Liabilities Measured on Recurring Basis
Long-term debt, fixed interest rate	7.50%	7.50%
Debt maturity date	2,021	2,021
Long term debt, premium	$ 3,175	$ 3,486
Senior Notes | 8.125% Senior Notes due 2022
Fair Value, Assets and Liabilities Measured on Recurring Basis
Long-term debt, fixed interest rate	8.125%	8.125%
Debt maturity date	2,022	2,022
Senior Notes | 7.5% Senior Notes due 2023
Fair Value, Assets and Liabilities Measured on Recurring Basis
Long-term debt, fixed interest rate	7.50%	7.50%
Debt maturity date	2,023	2,023
Long-term debt, discount	$ 3,294	$ 3,452

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details)	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Gulf Properties
Fair Value, Assets and Liabilities Measured on Recurring Basis
Fair value inputs, probability of default	3.59%	3.71%

Property, Plant and Equipment59

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Oil and natural gas properties
Proved	$ 12,199,049	$ 11,707,147
Unproved	261,657	290,596
Total oil and natural gas properties	12,460,706	11,997,743
Less: accumulated depreciation, depletion and impairment	(9,131,153)	(6,359,149)
Net oil and natural gas properties capitalized costs	3,329,553	5,638,594
Land	14,648	16,300
Non-oil and natural gas equipment	482,923	602,392
Buildings and structures	271,367	263,191
Total	768,938	881,883
Less accumulated depreciation and amortization	(212,090)	(305,420)
Other property, plant and equipment, net	556,848	576,463
Total property, plant and equipment, net	$ 3,886,401	$ 6,215,057

Property, Plant and Equipment60

Property, Plant and Equipment (Additional Information) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Oil and natural gas proved properties
Property, Plant and Equipment
Cumulative capitalized interest	$ 45.6	$ 38.1
Non-oil and natural gas equipment
Property, Plant and Equipment
Cumulative capitalized interest	4.3	4.3
Buildings and structures
Property, Plant and Equipment
Cumulative capitalized interest	$ 19.2	$ 17.1

Property, Plant and Equipment -

Property, Plant and Equipment - Narrative (Details)	3 Months Ended	6 Months Ended
	Jun. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)well	May. 31, 2015well	Dec. 31, 2014USD ($)
Property, Plant and Equipment
Cumulative full cost ceiling limitation impairment	$ 6,300,000,000	$ 6,300,000,000			$ 3,700,000,000
Full cost ceiling limitation impairment	1,500,000,000	2,600,000,000	$ 164,800,000
Repsol E&P USA, Inc.
Property, Plant and Equipment
Minimum net wells | well			484
Net wells | well				453
Repsol E&P USA, Inc. | Potential drilling carry costs
Property, Plant and Equipment
Drilling carry determination, amount per well short			$ 1,000,000
Repsol E&P USA, Inc.
Property, Plant and Equipment
Drilling carry received or billed			175,400,000
Maximum | Repsol E&P USA, Inc. | Potential drilling carry costs
Property, Plant and Equipment
Total drilling carry, maximum	31,000,000	31,000,000	$ 75,000,000
Other Current Assets | Permian Region | Drilling Assets
Property, Plant and Equipment
Assets classified as held-for-sale	$ 20,000,000	$ 20,000,000

Other Assets (Details)

Other Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Debt issuance costs, net of amortization	$ 83,065	$ 56,445
Deferred tax asset	52,763	95,843
Investments	10,882	11,106
Other	632	1,853
Total other assets	$ 147,342	$ 165,247

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Debt Instrument
Senior credit facility	$ 0	$ 0
Debt	4,395,639	3,195,436
Less: current maturities of long-term debt	0	0
Long-term debt	4,395,639	3,195,436
8.75% Senior Secured Notes due 2020
Debt Instrument
Debt	1,250,000	0
8.75% Senior Notes due 2020, net of $4,242 and $4,598 discount, respectively
Debt Instrument
Debt	445,758	445,402
7.5% Senior Notes due 2021, including premium of $3,175 and $3,486, respectively
Debt Instrument
Debt	1,149,175	1,178,486
8.125% Senior Notes due 2022
Debt Instrument
Debt	729,000	750,000
7.5% Senior Notes due 2023, net of $3,294 and $3,452 discount, respectively
Debt Instrument
Debt	821,706	821,548
Senior Secured Notes | 8.75% Senior Secured Notes due 2020
Debt Instrument
Debt	1,250,000	0
Senior Notes | 8.75% Senior Notes due 2020, net of $4,242 and $4,598 discount, respectively
Debt Instrument
Debt	445,758	445,402
Senior Notes | 7.5% Senior Notes due 2021, including premium of $3,175 and $3,486, respectively
Debt Instrument
Debt	1,149,175	1,178,486
Senior Notes | 8.125% Senior Notes due 2022
Debt Instrument
Debt	729,000	750,000
Senior Notes | 7.5% Senior Notes due 2023, net of $3,294 and $3,452 discount, respectively
Debt Instrument
Debt	$ 821,706	$ 821,548

Long-Term Debt (Additional Info

Long-Term Debt (Additional Information) (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
8.75% Senior Notes due 2020
Debt Instrument
Long term debt, discount	$ 4,242	$ 4,598
7.5% Senior Notes due 2021
Debt Instrument
Long term debt, premium	3,175	3,486
7.5% Senior Notes due 2023
Debt Instrument
Long term debt, discount	$ 3,294	$ 3,452
Senior Secured Notes
Debt Instrument
Long-term debt, fixed interest rate	8.75%
Senior Secured Notes | 8.75% Senior Secured Notes due 2020
Debt Instrument
Debt maturity date	2,020
Long-term debt, fixed interest rate	8.75%
Senior Notes | 8.75% Senior Notes due 2020
Debt Instrument
Debt maturity date	2,020	2,020
Long-term debt, fixed interest rate	8.75%	8.75%
Long term debt, discount	$ 4,242	$ 4,598
Senior Notes | 7.5% Senior Notes due 2021
Debt Instrument
Debt maturity date	2,021	2,021
Long-term debt, fixed interest rate	7.50%	7.50%
Long term debt, premium	$ 3,175	$ 3,486
Senior Notes | 8.125% Senior Notes due 2022
Debt Instrument
Debt maturity date	2,022	2,022
Long-term debt, fixed interest rate	8.125%	8.125%
Senior Notes | 7.5% Senior Notes due 2023
Debt Instrument
Debt maturity date	2,023	2,023
Long-term debt, fixed interest rate	7.50%	7.50%
Long term debt, discount	$ 3,294	$ 3,452

Long-Term Debt - Narrative (Det

Long-Term Debt - Narrative (Details) shares in Millions	Jun. 30, 2015USD ($)	Jun. 10, 2015USD ($)	Jun. 30, 2015USD ($)shares	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Jun. 09, 2015USD ($)	Dec. 31, 2014USD ($)
Debt Instrument
Write off of debt issuance costs					$ 7,108,000	$ 0
Carrying Value	$ 4,395,639,000		$ 4,395,639,000		4,395,639,000			$ 3,195,436,000
Common stock issued for debt exchange, aggregate principal amount					31,396,000	0
Gain on extinguishment of debt			17,934,000	$ 0	17,934,000	$ 0
8.75% Senior Secured Notes due 2020
Debt Instrument
Carrying Value	1,250,000,000		1,250,000,000		1,250,000,000			0
8.125% Senior Notes due 2022
Debt Instrument
Carrying Value	729,000,000		729,000,000		729,000,000			750,000,000
7.5% Senior Notes due 2021
Debt Instrument
Carrying Value	1,149,175,000		1,149,175,000		1,149,175,000			1,178,486,000
8.75% Senior Notes due 2020
Debt Instrument
Carrying Value	445,758,000		445,758,000		445,758,000			445,402,000
Senior credit facility
Debt Instrument
Borrowing base							$ 900,000,000
June Amendment | Senior credit facility
Debt Instrument
Maximum borrowing capacity		$ 1,000,000,000
Borrowing base	500,000,000		500,000,000		500,000,000
Write off of debt issuance costs		4,900,000
Additional aggregate principal indebtedness permitted (less than)		1,750,000,000
Reduction in borrowing base for every $1 junior lien debt incurred		$ 0.25
Senior credit facility
Debt Instrument
Covenant ratio of secured debt To EBITDA, maximum							2.25
Covenant, Ratio of EBITDA to interest expense at Mar 2015							2
Covenant, Ratio of EBITDA to interest expense at Jun 2015							2
Covenant, Ratio of EBITDA to interest expense at Sep 2015							1.75
Covenant, Ratio of EBITDA to interest expense at Dec 2015							1.50
Covenant, Ratio of EBITDA to interest expense at Mar 2016							1.50
Covenant, Ratio of EBITDA to interest expense at June 2016							1.50
Covenant, Ratio of EBITDA to interest expense at Sep 2016							1.50
Covenant, Ratio of EBITDA to interest expense at Dec 2016							2
Current assets to current liabilities, ratio minimum							1
Covenant, Ratio of total net debt to EBITDA at Jun 2016							6.25
Covenant, Ratio of total net debt to EBITDA at Sep 2016							6
Covenant, Ratio of total net debt to EBITDA at Dec 2016							6
Covenant, Ratio of total net debt to EBITDA at Mar 2017							5.50
Covenant, Ratio of total net debt to EBITDA at Jun 2017							5.50
Covenant, Ratio of total net debt to EBITDA at Sep 2017							5
Covenant, Ratio of total net debt to EBITDA at Dec 2017							5
Covenant, Ratio of total net debt to EBITDA at Mar 2018							4.50
Outstanding letters of credit	26,800,000		26,800,000		26,800,000
Senior credit facility | June Amendment
Debt Instrument
Covenant ratio of secured debt To EBITDA, maximum		2
Current assets to current liabilities, ratio minimum		1
Minimum collateral amount of proved oil, natural gas and NGL reserves representing the discounted present value of reserves used in borrowing base determination		80.00%
Senior credit facility | June Amendment | Maximum
Debt Instrument
Unused capacity, commitment fee percentage		0.50%
Senior credit facility | June Amendment | LIBOR | Minimum
Debt Instrument
Basis spread on variable rate		1.75%
Senior credit facility | June Amendment | LIBOR | Maximum
Debt Instrument
Basis spread on variable rate		2.75%
Senior credit facility | June Amendment | Federal Funds Rate
Debt Instrument
Basis spread on variable rate		0.50%
Senior credit facility | June Amendment | One-Month Eurodollar Rate
Debt Instrument
Basis spread on variable rate		1.00%
Senior credit facility | June Amendment | Base Rate | Minimum
Debt Instrument
Basis spread on variable rate		0.75%
Senior credit facility | June Amendment | Base Rate | Maximum
Debt Instrument
Basis spread on variable rate		1.75%
Junior lien debt | June Amendment
Debt Instrument
Outstanding junior debt threshold, reduction of maximum borrowing base		$ 1,500,000,000
Senior Secured Notes
Debt Instrument
Debt, face amount	1,250,000,000		$ 1,250,000,000		$ 1,250,000,000
Proceeds from issuance of debt, net of issuance costs	$ 1,210,000,000
Long-term debt, fixed interest rate	8.75%		8.75%		8.75%
Debt issuance costs	$ 37,000,000
Senior Secured Notes | 8.75% Senior Secured Notes due 2020
Debt Instrument
Carrying Value	$ 1,250,000,000		$ 1,250,000,000		$ 1,250,000,000			0
Long-term debt, fixed interest rate	8.75%		8.75%		8.75%
Senior Notes
Debt Instrument
Debt issuance cost, cumulative	$ 69,000,000		$ 69,000,000		$ 69,000,000
Senior Notes | 8.125% Senior Notes due 2022
Debt Instrument
Carrying Value	$ 729,000,000		$ 729,000,000		$ 729,000,000			$ 750,000,000
Long-term debt, fixed interest rate	8.125%		8.125%		8.125%			8.125%
Common stock issued for debt exchange, aggregate principal amount			$ 21,000,000
Senior Notes | 7.5% Senior Notes due 2021 and 8.125% Senior Notes due 2022
Debt Instrument
Common stock issued for debt exchange | shares			28
Common stock issued for debt exchange, aggregate principal amount			$ 50,000,000
Gain on extinguishment of debt			17,900,000		$ 17,900,000
Senior Notes | 7.5% Senior Notes due 2021
Debt Instrument
Carrying Value	$ 1,149,175,000		$ 1,149,175,000		$ 1,149,175,000			$ 1,178,486,000
Long-term debt, fixed interest rate	7.50%		7.50%		7.50%			7.50%
Common stock issued for debt exchange, aggregate principal amount			$ 29,000,000
Senior Notes | 8.75% Senior Notes due 2020
Debt Instrument
Carrying Value	$ 445,758,000		$ 445,758,000		$ 445,758,000			$ 445,402,000
Long-term debt, fixed interest rate	8.75%		8.75%		8.75%			8.75%
Aggregate outstanding principal amount of 8.75% senior notes due 2020 that would adjust maturity date of 8.75% senior secured notes due 2020	$ 100,000,000		$ 100,000,000		$ 100,000,000

Derivatives - Fair Value of Der

Derivatives - Fair Value of Derivative Contracts (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Derivatives, Fair Value
Derivative assets	$ 146,124	$ 338,417
Derivative liabilities	(2,207)	0
Total net derivative contracts	143,917	338,417
Current assets
Derivatives, Fair Value
Derivative assets	122,672	291,414
Noncurrent assets
Derivatives, Fair Value
Derivative assets	23,452	47,003
Current liabilities
Derivatives, Fair Value
Derivative liabilities	(2,199)	0
Noncurrent liabilities
Derivatives, Fair Value
Derivative liabilities	(8)	0
Oil Price Swaps | Current assets
Derivatives, Fair Value
Derivative assets	70,528	204,072
Oil Price Swaps | Noncurrent assets
Derivatives, Fair Value
Derivative assets	18,867	36,288
Natural Gas Price Swaps | Current assets
Derivatives, Fair Value
Derivative assets	4,757	29,648
Natural Gas Basis Swaps | Current assets
Derivatives, Fair Value
Derivative assets	0	350
Natural Gas Basis Swaps | Current liabilities
Derivatives, Fair Value
Derivative liabilities	(2,199)	0
Natural Gas Basis Swaps | Noncurrent liabilities
Derivatives, Fair Value
Derivative liabilities	(8)	0
Oil Collars - Three Way | Current assets
Derivatives, Fair Value
Derivative assets	46,825	56,289
Oil Collars - Three Way | Noncurrent assets
Derivatives, Fair Value
Derivative assets	4,585	10,715
Natural Gas Collars | Current assets
Derivatives, Fair Value
Derivative assets	$ 562	$ 1,055

Derivatives - Offsetting Assets

Derivatives - Offsetting Assets and Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Assets
Derivative assets, gross amounts	$ 146,124	$ 338,417
Derivative assets, gross amounts offset	(2,079)	0
Derivative assets, current	120,575	291,414
Derivative assets, noncurrent	23,470	47,003
Derivative assets, amounts net of offset	144,045	338,417
Derivative assets, financial collateral	0	0
Derivative assets, net amount	144,045	338,417
Liabilities
Derivative liabilities, gross amounts	2,207	0
Derivative liabilities, gross amounts offset	(2,079)	0
Derivative liabilities, current	102	0
Derivative liabilities, noncurrent	26	0
Derivative liabilities, amounts net of offset	128	0
Derivative liabilities, financial collateral	(128)	0
Derivative liabilities, net amount	0	0
Current assets
Assets
Derivative assets, gross amounts	122,672	291,414
Derivative assets, gross amounts offset	(2,097)	0
Derivative assets, financial collateral	0	0
Derivative assets, net amount	120,575	291,414
Noncurrent assets
Assets
Derivative assets, gross amounts	23,452	47,003
Derivative assets, gross amounts offset	18	0
Derivative assets, financial collateral	0	0
Derivative assets, net amount	23,470	47,003
Current liabilities
Liabilities
Derivative liabilities, gross amounts	2,199	0
Derivative liabilities, gross amounts offset	(2,097)	0
Derivative liabilities, financial collateral	(102)	0
Derivative liabilities, net amount	0	0
Noncurrent liabilities
Liabilities
Derivative liabilities, gross amounts	8	0
Derivative liabilities, gross amounts offset	18	0
Derivative liabilities, financial collateral	(26)	0
Derivative liabilities, net amount	$ 0	$ 0

Derivatives - Open Commodity De

Derivatives - Open Commodity Derivative Contracts (Details) - Jun. 30, 2015	$ / Mcf$ / bblMBblsMMcf
July 2015 - December 2015 | Oil Price Swaps
Derivative Instruments and Hedging Activities Disclosure
Notional (Oil in MBbls/Natural Gas in MMcf) | MBbls	1,570
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf)	93.02
July 2015 - December 2015 | Natural Gas Price Swaps
Derivative Instruments and Hedging Activities Disclosure
Notional (Oil in MBbls/Natural Gas in MMcf) | MMcf	3,680
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / Mcf	4.20
July 2015 - December 2015 | Natural Gas Basis Swaps
Derivative Instruments and Hedging Activities Disclosure
Notional (Oil in MBbls/Natural Gas in MMcf) | MMcf	31,280
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / Mcf	(0.30)
July 2015 - December 2015 | Oil Collars - Three Way
Derivative Instruments and Hedging Activities Disclosure
Notional (Oil in MBbls/Natural Gas in MMcf) | MBbls	3,128
July 2015 - December 2015 | Natural Gas Collars
Derivative Instruments and Hedging Activities Disclosure
Notional (Oil in MBbls/Natural Gas in MMcf) | MMcf	509
Collar Range, minimum | $ / Mcf	4
Collar Range, maximum | $ / Mcf	8.55
July 2015 - December 2015 | Sold Put | Oil Collars - Three Way
Derivative Instruments and Hedging Activities Disclosure
Collar Range, minimum	78.15
July 2015 - December 2015 | Purchased Put | Oil Collars - Three Way
Derivative Instruments and Hedging Activities Disclosure
Collar Range, minimum	90.03
July 2015 - December 2015 | Sold Call | Oil Collars - Three Way
Derivative Instruments and Hedging Activities Disclosure
Collar Range, maximum	103.65
January 2016 - December 2016 | Oil Price Swaps
Derivative Instruments and Hedging Activities Disclosure
Notional (Oil in MBbls/Natural Gas in MMcf) | MBbls	1,464
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf)	88.36
January 2016 - December 2016 | Natural Gas Basis Swaps
Derivative Instruments and Hedging Activities Disclosure
Notional (Oil in MBbls/Natural Gas in MMcf) | MMcf	10,980
Weighted Avg. Fixed Price (Oil in USD/bbl, Natural Gas in USD/mcf) | $ / Mcf	(0.38)
January 2016 - December 2016 | Oil Collars - Three Way
Derivative Instruments and Hedging Activities Disclosure
Notional (Oil in MBbls/Natural Gas in MMcf) | MBbls	2,556
January 2016 - December 2016 | Sold Put | Oil Collars - Three Way
Derivative Instruments and Hedging Activities Disclosure
Collar Range, minimum	83.14
January 2016 - December 2016 | Purchased Put | Oil Collars - Three Way
Derivative Instruments and Hedging Activities Disclosure
Collar Range, minimum	90
January 2016 - December 2016 | Sold Call | Oil Collars - Three Way
Derivative Instruments and Hedging Activities Disclosure
Collar Range, maximum	100.85

Derivatives - Narrative (Detail

Derivatives - Narrative (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)Institution	Jun. 30, 2014USD ($)
Derivative Instruments and Hedging Activities Disclosure
Number of counterparties to open derivative contracts | Institution			9
Loss (gain) on derivative contracts	$ 33,004	$ 85,292	$ (16,823)	$ 127,783
Commodity Derivatives
Derivative Instruments and Hedging Activities Disclosure
Loss (gain) on derivative contracts	33,000	85,300	(16,800)	127,800
Commodity Derivatives | Cash
Derivative Instruments and Hedging Activities Disclosure
Loss (gain) on derivative contracts	$ (74,400)	13,100	$ (211,300)	$ 96,400
Early Settlements | Commodity Derivatives | Cash
Derivative Instruments and Hedging Activities Disclosure
Loss (gain) on derivative contracts		$ 69,600
Lenders of Senior Credit Facility
Derivative Instruments and Hedging Activities Disclosure
Number of counterparties to open derivative contracts | Institution			5

Asset Retirement Obligations -

Asset Retirement Obligations - Reconciliation of Beginning and Ending Aggregate Carrying Amounts of Asset Retirement Obligations (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2015	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis
Asset retirement obligations at December 31, 2014	$ 54,402
Liability incurred upon acquiring and drilling wells	860
Liability settled or disposed in current period	(369)
Accretion	2,191
Asset retirement obligations at June 30, 2015	$ 54,402	$ 57,084	$ 54,402
Less: current portion		0
Asset retirement obligations		$ 57,084	$ 54,402

Commitments and Contingencies -

Commitments and Contingencies - Narrative (Details) $ in Millions	May. 27, 2015USD ($)	Jun. 30, 2015USD ($)bcfclaim$ / Mcf	Jun. 30, 2015USD ($)bcfclaim$ / Mcf	Dec. 31, 2014USD ($)bcf$ / Mcf
James Hart And Other Named Plaintiffs
Commitments and Contingencies Disclosure
Litigation settlement, agreement in principle	$ 5
Wesley West Minerals, Ltd and Longfellow Ranch Partners, LP
Commitments and Contingencies Disclosure
Damages sought by plaintiff			$ 45.5
General Land Office of the State of Texas
Commitments and Contingencies Disclosure
Damages sought by plaintiff			13
Patriot Exploration, LLC, Jonathan Feldman, Redwing Drilling Partners, Mapleleaf Drilling Partners, Avalanche Drilling Partners, Penguin Drilling Partners and Gramax Insurance Company Ltd.
Commitments and Contingencies Disclosure
Settlement amount			$ 4
Shareholder Derivative Actions
Commitments and Contingencies Disclosure
Number of shareholder derivative actions claims filed | claim		7	7
Treating Agreement
Commitments and Contingencies Disclosure
Contract agreement, term			30 years
Minimum delivery required (in Bcf) | bcf		3,200	3,200
Initial shortfall price per Mcf | $ / Mcf		0.25	0.25
Delivery made (in Bcf) | bcf				54.7
Delivery shortfall (in Bcf) | bcf				300.1
Cumulative shortfall accrued		$ 92.4	$ 92.4	$ 75
Final shortfall price per Mcf | $ / Mcf		0.70	0.70	0.70
Final shortfall, if not delivered in future periods		$ 103.9	$ 103.9	$ 210.1
Shortfall amount accrued		8.7	17.2
Annual minimum delivery requirement shortfall. 2012 to 2019, assuming no deliveries subsequent to balance sheet date		290.2	290.2
Delivery requirement reduction payment		290.5	290.5
Treating Agreement | Minimum
Commitments and Contingencies Disclosure
Projected shortfall amount		31	31
Treating Agreement | Maximum
Commitments and Contingencies Disclosure
Projected shortfall amount		$ 38	$ 38

Equity - Treasury Stock Activit

Equity - Treasury Stock Activity (Details) - USD ($) shares in Thousands, $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Equity, Class of Treasury Stock [Line Items]
Value of shares withheld for taxes	$ 2,093
Retirement of treasury stock	$ 0
Treasury Stock
Equity, Class of Treasury Stock [Line Items]
Number of shares withheld for taxes	1,279	637
Value of shares withheld for taxes	$ 2,093	$ 3,865
Retirement of treasury stock (in shares)	1,279	637
Retirement of treasury stock	$ 2,093	$ 3,865

Equity - Narrative (Details)

Equity - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended			6 Months Ended
	Jun. 30, 2015	Dec. 31, 2014	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	May. 15, 2015
Equity Disclosure
Common stock, shares authorized	1,800,000,000	800,000,000		1,800,000,000
Preferred stock, shares authorized	50,000,000	50,000,000		50,000,000
Reduction to preferred stock dividends	$ 7,074		$ 13,881	$ 17,955	$ 27,763
Additional paid-in capital—stockholder receivable	$ 2,500	$ 2,500		$ 2,500
8.5% Convertible perpetual preferred stock
Equity Disclosure
Preferred stock, dividend rate, percentage				8.50%	8.50%
Cash dividends				$ 11,300
Preferred stock, shares outstanding	2,650,000	2,650,000		2,650,000
6.0% Convertible perpetual preferred stock
Equity Disclosure
Preferred stock, dividend rate, percentage					6.00%
Shares of common stock issued related to the conversion of 6% preferred stock (in shares)		18,400,000
7.0% Convertible perpetual preferred stock
Equity Disclosure
Preferred stock, dividend rate, percentage				7.00%	7.00%
Number of trading days used in calculation of value of shares issued				15 days
Percentage multiplier used in calculation of value of shares issued				95.00%
Dividends declared, per share	$ 3.50			$ 3.50
Convertible perpetual preferred stock dividends, common stock issued (in shares)				5,700,000
Market value of common stock issued as dividends				$ 6,700
Common stock issued, value per preferred share						$ 2.23
Preferred stock, shares outstanding	3,000,000	3,000,000		3,000,000
Reduction to preferred stock dividends	$ (3,800)			$ (3,800)
Common and Preferred Stock
Equity Disclosure
Shares authorized	1,850,000,000	850,000,000		1,850,000,000
Shares authorized, par value (usd per share)	$ 0.001	$ 0.001		$ 0.001

Income Taxes - Provision for In

Income Taxes - Provision for Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Current
Federal	$ 0	$ 0	$ 0	$ 0
State	25	(1,194)	65	(1,067)
Current, total	25	(1,194)	65	(1,067)
Deferred
Federal	0	0	0	0
State	0	0	0	0
Deferred, total	0	0	0	0
Total provision	25	(1,194)	65	(1,067)
Noncontrolling Interest
Deferred
Total provision	19	88	49	170
Parent
Deferred
Total provision	$ 6	$ (1,282)	$ 16	$ (1,237)

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2010
Income Taxes
Federal net operating loss carryforwards subject to the IRC Section 382 limitation			$ 929.4
Unrecognized tax benefits	$ 0.1	$ 0.1
Minimum
Income Taxes
Number of tax years open for state tax audit (in years)	3 years
Maximum
Income Taxes
Number of tax years open for state tax audit (in years)	5 years
Domestic Tax Authority | Earliest Tax Year
Income Taxes
Open tax year	2,011
Net Operating Loss And Other Carryforwards | Earliest Tax Year
Income Taxes
Open tax year	2,005
Net Operating Loss And Other Carryforwards | Latest Tax Year
Income Taxes
Open tax year	2,010

Loss per Share - Calculation of

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	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Earnings Per Share [Abstract]
Net Loss, Basic	$ (1,375,556)	$ (46,775)	$ (2,421,390)	$ (196,993)
Weighted average shares, basic	495,153	485,318	486,704	485,059
Loss Per Share, Basic	$ (2.78)	$ (0.10)	$ (4.98)	$ (0.41)
Effect of dilutive securities
Restricted stock (in dollars)	$ 0	$ 0	$ 0	$ 0
Restricted stock (in shares)	0	0	0	0
Convertible preferred stock (in dollars)	$ 0	$ 0	$ 0	$ 0
Convertible preferred stock (in shares)	0	0	0	0
Net Loss, Diluted	$ (1,375,556)	$ (46,775)	$ (2,421,390)	$ (196,993)
Weighted average shares, diluted	495,153	485,318	486,704	485,059
Loss Per Share, Diluted	$ (2.78)	$ (0.10)	$ (4.98)	$ (0.41)

Loss per Share - Calculation 77

Loss per Share - Calculation of Weighted Average Common Shares Outstanding used in Computation of Diluted Earnings (Loss) Per Share (Additional Information) (Details) - shares shares in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Restricted Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)		2		2.6
Convertible Preferred Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)	71.7	90.1	71.7	90.1
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%
6.0% Convertible perpetual preferred stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Preferred stock, dividend rate, percentage				6.00%
7.0% Convertible perpetual preferred stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Preferred stock, dividend rate, percentage			7.00%	7.00%

Related Party Transactions - Na

Related Party Transactions - Narrative (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Former Chairman and CEO Severance
Related Party Transaction
Severance, liability	$ 2.4	$ 3.1

Share-Based Compensation - Summ

Share-Based Compensation - Summary of Unvested Restricted Stock Awards (Details) - 6 months ended Jun. 30, 2015 - Restricted Stock - $ / shares shares in Thousands	Total
Number of Shares
Unvested shares/units outstanding at beginning of period	8,556
Granted	662
Vested	(3,030)
Forfeited / Canceled	(575)
Unvested shares/units outstanding at end of period	5,613
Weighted- Average Grant Date Fair Value (usd per share)
Unvested restricted shares outstanding at beginning of period	$ 6.39
Granted	1.78
Vested	6.34
Forfeited / Canceled	6.39
Unvested restricted shares outstanding at end of period	$ 5.88

Share-Based Compensation - Su80

Share-Based Compensation - Summary of Unvested Restricted Stock Units (Details) - Jun. 30, 2015 - Restricted Stock Units - $ / shares shares in Thousands	Total
Vesting Four Years from Grant Date
Number of Shares
Unvested shares/units outstanding at beginning of period	0
Granted	8,945
Vested	(827)
Forfeited / Canceled	(543)
Unvested shares/units outstanding at end of period	7,575
Fair value per unit (usd per share)
Fair Value per Unit at end of period (usd per share)	$ 0.88
Vesting Two Years from Grant Date
Number of Shares
Unvested shares/units outstanding at beginning of period	0
Granted	2,398
Vested	0
Forfeited / Canceled	(122)
Unvested shares/units outstanding at end of period	2,276
Minimum | Vesting Two Years from Grant Date
Fair value per unit (usd per share)
Fair Value per Unit at end of period (usd per share)	$ 0.51
Maximum | Vesting Two Years from Grant Date
Fair value per unit (usd per share)
Fair Value per Unit at end of period (usd per share)	$ 0.73

Share-Based Compensation - Perf

Share-Based Compensation - Performance Units/Performance Share Units - Fair Value Assumptions (Details) - $ / shares	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Performance Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected price volatility range, minimum	25.70%	26.60%
Expected price volatility range, maximum	89.70%	86.60%
Weighted-average risk-free interest rate	0.30%	0.50%
Weighted-average fair value per unit (usd per unit)	$ 1.41	$ 13.85
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected price volatility range, minimum	29.00%
Expected price volatility range, maximum	77.20%
Weighted-average risk-free interest rate	0.90%
Weighted-average fair value per unit (usd per unit)	$ 0.52

Share-Based Compensation - Pe82

Share-Based Compensation - Performance Units/Performance Share Units Activity (Details) - Jun. 30, 2015 - shares shares in Thousands	Total
Performance Units
Number of Shares
Outstanding at beginning of period	66
Granted	0
Forfeited /canceled	0
Outstanding at end of period	66
Performance Units | Performance Period Ending December 2015
Number of Shares
Vested	22
Unvested	6
Performance Units | Performance Period Ending December 2016
Number of Shares
Vested	15
Unvested	23
Performance Share Units
Number of Shares
Outstanding at beginning of period	0
Granted	2,044
Forfeited /canceled	(151)
Outstanding at end of period	1,893
Performance Share Units | Performance Period Ending December 2017
Number of Shares
Vested	0
Unvested	1,893

Share-Based Compensation - Narr

Share-Based Compensation - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ 8.2	$ 7.3	$ 13.9	$ 15.5
Share-based compensation, capitalized	1.3	$ 1.9	$ 2.6	$ 3.1
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)			4 years
Unrecognized compensation cost related to unvested awards	25		$ 25
Unrecognized compensation cost, period of recognition (in years)			2 years
Performance Unit and Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)			3 years
Vesting Four Years from Grant Date | Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)			4 years
Unrecognized compensation cost related to unvested awards	5.4		$ 5.4
Unrecognized compensation cost, period of recognition (in years)			2 years 1 month
Vesting Two Years from Grant Date | Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)			2 years
Unrecognized compensation cost related to unvested awards	$ 1		$ 1
Unrecognized compensation cost, period of recognition (in years)			1 year 1 month
Percentage vesting at the end of the first year			40.00%
Percentage vesting at the end of the second year			60.00%
Discount from common stock price using a credit spread, percentage			3.60%

Business Segment Information -

Business Segment Information - Summarized Financial Information Concerning Segments (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)business_unitsegment	Jun. 30, 2014USD ($)	Dec. 31, 2014USD ($)
Segment Reporting Information
Reportable segments | segment			3
Business units | business_unit			3
Total revenues	$ 229,607	$ 374,714	$ 444,915	$ 817,770
Loss from operations	(1,535,083)	42,079	(2,623,539)	(40,251)
Interest expense, net	(73,727)	(61,863)	(136,569)	(123,906)
Gain on extinguishment of debt	17,934	0	17,934	0
Other (expense) income, net	2,170	1,338	1,634	3,432
Loss before income taxes	(1,588,706)	(18,446)	(2,740,540)	(160,725)
Capital expenditures	167,566	376,937	487,756	652,710
Depreciation, depletion, amortization and accretion	107,917	113,743	228,451	250,196
Total assets	5,435,048		5,435,048		$ 7,259,225
Exploration and Production
Segment Reporting Information
Total revenues	214,532	339,906	410,264	747,244
Loss from operations	(1,511,600)	69,782	(2,565,759)	13,306
Interest expense, net	(23)	(4)	(40)	139
Gain on extinguishment of debt	0		0
Other (expense) income, net	1,630	(49)	1,176	(234)
Loss before income taxes	(1,509,993)	69,729	(2,564,623)	13,211
Capital expenditures	151,440	356,568	453,503	620,809
Depreciation, depletion, amortization and accretion	95,430	98,357	202,640	219,398
Total assets	3,708,676		3,708,676		6,273,802
Drilling and Oil Field Services
Segment Reporting Information
Total revenues	5,241	18,829	15,086	35,932
Loss from operations	(3,754)	(2,347)	(11,526)	(5,449)
Interest expense, net	0	0	0	0
Gain on extinguishment of debt	0		0
Other (expense) income, net	4	(75)	0	(473)
Loss before income taxes	(3,750)	(2,422)	(11,526)	(5,922)
Capital expenditures	598	6,654	2,472	7,275
Depreciation, depletion, amortization and accretion	5,000	7,661	10,760	15,372
Total assets	91,905		91,905		115,083
Midstream Services
Segment Reporting Information
Total revenues	8,606	14,874	17,370	32,519
Loss from operations	(3,154)	(2,345)	(7,027)	(3,756)
Interest expense, net	0	0	0	0
Gain on extinguishment of debt	0		0
Other (expense) income, net	9	0	13	0
Loss before income taxes	(3,145)	(2,345)	(7,014)	(3,756)
Capital expenditures	8,249	5,808	16,681	11,766
Depreciation, depletion, amortization and accretion	2,793	2,509	5,473	4,950
Total assets	221,064		221,064		219,691
All Other
Segment Reporting Information
Total revenues	1,228	1,105	2,195	2,075
Loss from operations	(16,575)	(23,011)	(39,227)	(44,352)
Interest expense, net	(73,704)	(61,859)	(136,529)	(124,045)
Gain on extinguishment of debt	17,934		17,934
Other (expense) income, net	527	1,462	445	4,139
Loss before income taxes	(71,818)	(83,408)	(157,377)	(164,258)
Capital expenditures	7,279	7,907	15,100	12,860
Depreciation, depletion, amortization and accretion	4,694	5,216	9,578	10,476
Total assets	1,413,403		1,413,403		$ 650,649
Operating Segments
Segment Reporting Information
Total revenues	253,705	431,322	496,574	933,005
Operating Segments | Exploration and Production
Segment Reporting Information
Total revenues	214,534	339,906	410,277	747,244
Operating Segments | Drilling and Oil Field Services
Segment Reporting Information
Total revenues	17,161	51,891	41,790	98,971
Operating Segments | Midstream Services
Segment Reporting Information
Total revenues	20,782	38,420	42,312	84,715
Operating Segments | All Other
Segment Reporting Information
Total revenues	1,228	1,105	2,195	2,075
Intersegment Eliminations
Segment Reporting Information
Total revenues	(24,098)	(56,608)	(51,659)	(115,235)
Intersegment Eliminations | Exploration and Production
Segment Reporting Information
Total revenues	(2)	0	(13)	0
Intersegment Eliminations | Drilling and Oil Field Services
Segment Reporting Information
Total revenues	(11,920)	(33,062)	(26,704)	(63,039)
Intersegment Eliminations | Midstream Services
Segment Reporting Information
Total revenues	(12,176)	(23,546)	(24,942)	(52,196)
Intersegment Eliminations | All Other
Segment Reporting Information
Total revenues	$ 0	$ 0	$ 0	$ 0

Business Segment Information 85

Business Segment Information - Summarized Financial Information Concerning Segments (Additional Information) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Segment Reporting Information
Full cost ceiling limitation impairment	$ 1,500,000		$ 2,600,000	$ 164,800
Impairment	1,489,391	$ 3,133	2,573,257	167,912
Exploration and Production
Segment Reporting Information
Full cost ceiling limitation impairment	1,500,000		2,600,000	164,800
Drilling and Oil Field Services
Segment Reporting Information
Impairment		$ 3,100		$ 3,100
Assets classified as held-for-sale	$ 20,000		$ 20,000

Condensed Consolidating Finan86

Condensed Consolidating Financial Information - Condensed Consolidating Balance Sheets of SandRidge Energy, Inc. and Wholly Owned Subsidiary Guarantors and Non-Guarantors (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014	Jun. 30, 2014	Dec. 31, 2013
Current assets
Cash and cash equivalents	$ 983,617	$ 181,253	$ 918,758	$ 814,663
Accounts receivable, net	237,720	330,077
Intercompany accounts receivable	0	0
Derivative contracts	120,575	291,414
Prepaid expenses	9,938	7,981
Other current assets	25,985	21,193
Total current assets	1,377,835	831,918
Property, plant and equipment, net	3,886,401	6,215,057
Investment in subsidiaries	0	0
Derivative contracts	23,470	47,003
Other assets	147,342	165,247
Total assets	5,435,048	7,259,225
Current liabilities
Accounts payable and accrued expenses	494,675	683,392
Intercompany accounts payable	0	0
Derivative contracts	102	0
Deferred tax liability	52,763	95,843
Other current liabilities	3,791	5,216
Total current liabilities	551,331	784,451
Investment in subsidiaries	0	0
Long-term debt	4,395,639	3,195,436
Derivative contracts	26	0
Asset retirement obligations	57,084	54,402
Other long-term obligations	15,396	15,116
Total liabilities	5,019,476	4,049,405
Equity
SandRidge Energy, Inc. stockholders’ equity	(434,563)	1,937,825
Noncontrolling interest	850,135	1,271,995
Total equity	415,572	3,209,820
Total liabilities and equity	5,435,048	7,259,225
Parent
Current assets
Cash and cash equivalents	970,115	170,468	910,633	805,505
Accounts receivable, net	7	7
Intercompany accounts receivable	1,026,442	751,376
Derivative contracts	0	0
Prepaid expenses	0	0
Other current assets	0	0
Total current assets	1,996,564	921,851
Property, plant and equipment, net	0	0
Investment in subsidiaries	4,307,423	6,606,198
Derivative contracts	0	0
Other assets	135,828	152,286
Total assets	6,439,815	7,680,335
Current liabilities
Accounts payable and accrued expenses	177,231	201,368
Intercompany accounts payable	1,328,602	1,315,667
Derivative contracts	0	0
Deferred tax liability	52,763	95,843
Other current liabilities	0	0
Total current liabilities	1,558,596	1,612,878
Investment in subsidiaries	914,164	928,217
Long-term debt	4,401,541	3,201,338
Derivative contracts	0
Asset retirement obligations	0	0
Other long-term obligations	77	77
Total liabilities	6,874,378	5,742,510
Equity
SandRidge Energy, Inc. stockholders’ equity	(434,563)	1,937,825
Noncontrolling interest	0	0
Total equity	(434,563)	1,937,825
Total liabilities and equity	6,439,815	7,680,335
Guarantors
Current assets
Cash and cash equivalents	4,440	1,398	1,249	1,013
Accounts receivable, net	228,493	299,764
Intercompany accounts receivable	1,341,801	1,339,152
Derivative contracts	120,575	284,825
Prepaid expenses	9,926	7,971
Other current assets	25,985	21,193
Total current assets	1,731,220	1,954,303
Property, plant and equipment, net	3,334,417	5,137,702
Investment in subsidiaries	7,878	25,944
Derivative contracts	23,470	47,003
Other assets	16,785	18,197
Total assets	5,113,770	7,183,149
Current liabilities
Accounts payable and accrued expenses	316,001	477,399
Intercompany accounts payable	1,040,026	780,645
Derivative contracts	14,343	38,454
Deferred tax liability	0	0
Other current liabilities	3,791	5,216
Total current liabilities	1,374,161	1,301,714
Investment in subsidiaries	273,921	134,013
Long-term debt	0	0
Derivative contracts	26
Asset retirement obligations	57,084	54,402
Other long-term obligations	15,319	15,039
Total liabilities	1,720,511	1,505,168
Equity
SandRidge Energy, Inc. stockholders’ equity	3,393,259	5,677,981
Noncontrolling interest	0	0
Total equity	3,393,259	5,677,981
Total liabilities and equity	5,113,770	7,183,149
Non-Guarantors
Current assets
Cash and cash equivalents	9,062	9,387	6,876	8,145
Accounts receivable, net	9,227	30,313
Intercompany accounts receivable	35,566	41,679
Derivative contracts	14,241	45,043
Prepaid expenses	12	10
Other current assets	0	0
Total current assets	68,108	126,432
Property, plant and equipment, net	551,984	1,077,355
Investment in subsidiaries	0	0
Derivative contracts	0	0
Other assets	631	666
Total assets	620,723	1,204,453
Current liabilities
Accounts payable and accrued expenses	1,450	4,632
Intercompany accounts payable	35,181	35,895
Derivative contracts	0	0
Deferred tax liability	0	0
Other current liabilities	0	0
Total current liabilities	36,631	40,527
Investment in subsidiaries	0	0
Long-term debt	0	0
Derivative contracts	0
Asset retirement obligations	0	0
Other long-term obligations	0	0
Total liabilities	36,631	40,527
Equity
SandRidge Energy, Inc. stockholders’ equity	584,092	1,163,926
Noncontrolling interest	0	0
Total equity	584,092	1,163,926
Total liabilities and equity	620,723	1,204,453
Eliminations
Current assets
Cash and cash equivalents	0	0	$ 0	$ 0
Accounts receivable, net	(7)	(7)
Intercompany accounts receivable	(2,403,809)	(2,132,207)
Derivative contracts	(14,241)	(38,454)
Prepaid expenses	0	0
Other current assets	0	0
Total current assets	(2,418,057)	(2,170,668)
Property, plant and equipment, net	0	0
Investment in subsidiaries	(4,315,301)	(6,632,142)
Derivative contracts	0	0
Other assets	(5,902)	(5,902)
Total assets	(6,739,260)	(8,808,712)
Current liabilities
Accounts payable and accrued expenses	(7)	(7)
Intercompany accounts payable	(2,403,809)	(2,132,207)
Derivative contracts	(14,241)	(38,454)
Deferred tax liability	0	0
Other current liabilities	0	0
Total current liabilities	(2,418,057)	(2,170,668)
Investment in subsidiaries	(1,188,085)	(1,062,230)
Long-term debt	(5,902)	(5,902)
Derivative contracts	0
Asset retirement obligations	0	0
Other long-term obligations	0	0
Total liabilities	(3,612,044)	(3,238,800)
Equity
SandRidge Energy, Inc. stockholders’ equity	(3,977,351)	(6,841,907)
Noncontrolling interest	850,135	1,271,995
Total equity	(3,127,216)	(5,569,912)
Total liabilities and equity	$ (6,739,260)	$ (8,808,712)

Condensed Consolidating Finan87

Condensed Consolidating Financial Information - Condensed Consolidating Statements of Operations of SandRidge Energy, Inc. and Wholly Owned Subsidiary Guarantors and Non-Guarantors (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Condensed Financial Statements, Captions
Total revenues	$ 229,607	$ 374,714	$ 444,915	$ 817,770
Expenses
Direct operating expenses	98,766	98,516	213,712	241,660
General and administrative	38,382	31,915	74,531	70,453
Depreciation, depletion, amortization and accretion	107,917	113,743	228,451	250,196
Impairment	1,489,391	3,133	2,573,257	167,912
Loss (gain) on derivative contracts	33,004	85,292	(16,823)	127,783
(Gain) loss on sale of assets	(2,770)	36	(4,674)	17
Total expenses	1,764,690	332,635	3,068,454	858,021
Loss from operations	(1,535,083)	42,079	(2,623,539)	(40,251)
Equity earnings from subsidiaries	0	0	0	0
Interest (expense) income	(73,727)	(61,863)	(136,569)	(123,906)
Gain on extinguishment of debt	17,934	0	17,934	0
Other income, net	2,170	1,338	1,634	3,432
Loss before income taxes	(1,588,706)	(18,446)	(2,740,540)	(160,725)
Income tax expense	25	(1,194)	65	(1,067)
Net loss	(1,588,731)	(17,252)	(2,740,605)	(159,658)
Less: net (loss) income attributable to noncontrolling interest	(220,249)	15,642	(337,170)	9,572
Net loss attributable to SandRidge Energy, Inc.	(1,368,482)	(32,894)	(2,403,435)	(169,230)
Parent
Condensed Financial Statements, Captions
Total revenues	0	0	0	0
Expenses
Direct operating expenses	0	0	0	0
General and administrative	61	71	117	220
Depreciation, depletion, amortization and accretion	0	0	0	0
Impairment	0	0	0	0
Loss (gain) on derivative contracts	0	0	0	0
(Gain) loss on sale of assets	0	0	0	0
Total expenses	61	71	117	220
Loss from operations	(61)	(71)	(117)	(220)
Equity earnings from subsidiaries	(1,312,652)	27,725	(2,284,723)	(46,259)
Interest (expense) income	(73,703)	(61,859)	(136,529)	(124,045)
Gain on extinguishment of debt	17,934		17,934
Other income, net	0	0	0	0
Loss before income taxes	(1,368,482)	(34,205)	(2,403,435)	(170,524)
Income tax expense	0	(1,311)	0	(1,294)
Net loss	(1,368,482)	(32,894)	(2,403,435)	(169,230)
Less: net (loss) income attributable to noncontrolling interest	0	0	0	0
Net loss attributable to SandRidge Energy, Inc.	(1,368,482)	(32,894)	(2,403,435)	(169,230)
Guarantors
Condensed Financial Statements, Captions
Total revenues	203,591	314,521	396,112	693,570
Expenses
Direct operating expenses	95,832	93,597	207,950	232,018
General and administrative	37,379	30,481	72,598	67,426
Depreciation, depletion, amortization and accretion	98,416	99,237	208,269	219,814
Impairment	1,164,834	3,133	2,068,069	125,599
Loss (gain) on derivative contracts	29,067	67,509	(15,042)	101,611
(Gain) loss on sale of assets	(2,770)	36	(4,670)	17
Total expenses	1,422,758	293,993	2,537,174	746,485
Loss from operations	(1,219,167)	20,528	(2,141,062)	(52,915)
Equity earnings from subsidiaries	(95,545)	5,863	(145,166)	3,086
Interest (expense) income	(24)	(4)	(40)	139
Gain on extinguishment of debt	0		0
Other income, net	2,084	1,338	1,545	3,431
Loss before income taxes	(1,312,652)	27,725	(2,284,723)	(46,259)
Income tax expense	0	0	0	0
Net loss	(1,312,652)	27,725	(2,284,723)	(46,259)
Less: net (loss) income attributable to noncontrolling interest	0	0	0	0
Net loss attributable to SandRidge Energy, Inc.	(1,312,652)	27,725	(2,284,723)	(46,259)
Non-Guarantors
Condensed Financial Statements, Captions
Total revenues	26,016	60,205	48,811	124,299
Expenses
Direct operating expenses	2,934	4,931	5,770	9,741
General and administrative	942	1,363	1,816	2,807
Depreciation, depletion, amortization and accretion	9,501	14,506	20,182	30,382
Impairment	324,557	0	505,188	42,313
Loss (gain) on derivative contracts	3,937	17,783	(1,781)	26,172
(Gain) loss on sale of assets	0	0	(4)	0
Total expenses	341,871	38,583	531,171	111,415
Loss from operations	(315,855)	21,622	(482,360)	12,884
Equity earnings from subsidiaries	0	0	0	0
Interest (expense) income	0	0	0	0
Gain on extinguishment of debt	0		0
Other income, net	86	0	89	1
Loss before income taxes	(315,769)	21,622	(482,271)	12,885
Income tax expense	25	117	65	227
Net loss	(315,794)	21,505	(482,336)	12,658
Less: net (loss) income attributable to noncontrolling interest	0	0	0	0
Net loss attributable to SandRidge Energy, Inc.	(315,794)	21,505	(482,336)	12,658
Eliminations
Condensed Financial Statements, Captions
Total revenues	0	(12)	(8)	(99)
Expenses
Direct operating expenses	0	(12)	(8)	(99)
General and administrative	0	0	0	0
Depreciation, depletion, amortization and accretion	0	0	0	0
Impairment	0	0	0	0
Loss (gain) on derivative contracts	0	0	0	0
(Gain) loss on sale of assets	0	0	0	0
Total expenses	0	(12)	(8)	(99)
Loss from operations	0	0	0	0
Equity earnings from subsidiaries	1,408,197	(33,588)	2,429,889	43,173
Interest (expense) income	0	0	0	0
Gain on extinguishment of debt	0		0
Other income, net	0	0	0	0
Loss before income taxes	1,408,197	(33,588)	2,429,889	43,173
Income tax expense	0	0	0	0
Net loss	1,408,197	(33,588)	2,429,889	43,173
Less: net (loss) income attributable to noncontrolling interest	(220,249)	15,642	(337,170)	9,572
Net loss attributable to SandRidge Energy, Inc.	$ 1,628,446	$ (49,230)	$ 2,767,059	$ 33,601

Condensed Consolidating Finan88

Condensed Consolidating Financial Information - Condensed Consolidating Statements of Cash Flows of SandRidge Energy, Inc. and Wholly Owned Subsidiary Guarantors and Non-Guarantors (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Condensed Financial Statements, Captions
Net cash (used in) provided by operating activities	$ 318,994	$ 230,792
Cash flows from investing activities
Capital expenditures for property, plant and equipment	(636,822)	(656,699)
Proceeds from sale of assets	11,462	707,799
Other	7,987	(16,553)
Net cash (used in) provided by investing activities	(628,835)	34,547
Cash flows from financing activities
Proceeds from borrowings	2,190,000	0
Repayments of borrowings	(940,000)	0
Distributions to unitholders	(84,690)	(103,142)
Intercompany borrowings (advances), net	0	0
Other	(53,105)	(58,102)
Net cash provided by (used in) financing activities	1,112,205	(161,244)
Net increase (decrease) in cash and cash equivalents	802,364	104,095
CASH AND CASH EQUIVALENTS, beginning of year	181,253	814,663
CASH AND CASH EQUIVALENTS, end of period	983,617	918,758
Parent
Condensed Financial Statements, Captions
Net cash (used in) provided by operating activities	(122,181)	(119,006)
Cash flows from investing activities
Capital expenditures for property, plant and equipment	0	0
Proceeds from sale of assets		0
Other	0	0
Net cash (used in) provided by investing activities	0	0
Cash flows from financing activities
Proceeds from borrowings	2,190,000
Repayments of borrowings	(940,000)
Distributions to unitholders	0	0
Intercompany borrowings (advances), net	(275,066)	257,498
Other	(53,106)	(33,364)
Net cash provided by (used in) financing activities	921,828	224,134
Net increase (decrease) in cash and cash equivalents	799,647	105,128
CASH AND CASH EQUIVALENTS, beginning of year	170,468	805,505
CASH AND CASH EQUIVALENTS, end of period	970,115	910,633
Guarantors
Condensed Financial Statements, Captions
Net cash (used in) provided by operating activities	344,778	228,860
Cash flows from investing activities
Capital expenditures for property, plant and equipment	(636,822)	(656,699)
Proceeds from sale of assets		707,799
Other	(65,989)	(104,286)
Net cash (used in) provided by investing activities	(702,811)	(53,186)
Cash flows from financing activities
Proceeds from borrowings	0
Repayments of borrowings	0
Distributions to unitholders	0	0
Intercompany borrowings (advances), net	276,384	(257,879)
Other	84,691	82,441
Net cash provided by (used in) financing activities	361,075	(175,438)
Net increase (decrease) in cash and cash equivalents	3,042	236
CASH AND CASH EQUIVALENTS, beginning of year	1,398	1,013
CASH AND CASH EQUIVALENTS, end of period	4,440	1,249
Non-Guarantors
Condensed Financial Statements, Captions
Net cash (used in) provided by operating activities	65,902	126,424
Cash flows from investing activities
Capital expenditures for property, plant and equipment	0	0
Proceeds from sale of assets		0
Other	5	1,061
Net cash (used in) provided by investing activities	5	1,061
Cash flows from financing activities
Proceeds from borrowings	0
Repayments of borrowings	0
Distributions to unitholders	(97,498)	(127,985)
Intercompany borrowings (advances), net	(1,318)	381
Other	32,584	(1,150)
Net cash provided by (used in) financing activities	(66,232)	(128,754)
Net increase (decrease) in cash and cash equivalents	(325)	(1,269)
CASH AND CASH EQUIVALENTS, beginning of year	9,387	8,145
CASH AND CASH EQUIVALENTS, end of period	9,062	6,876
Eliminations
Condensed Financial Statements, Captions
Net cash (used in) provided by operating activities	30,495	(5,486)
Cash flows from investing activities
Capital expenditures for property, plant and equipment	0	0
Proceeds from sale of assets		0
Other	73,971	86,672
Net cash (used in) provided by investing activities	73,971	86,672
Cash flows from financing activities
Proceeds from borrowings	0
Repayments of borrowings	0
Distributions to unitholders	12,808	24,843
Intercompany borrowings (advances), net	0	0
Other	(117,274)	(106,029)
Net cash provided by (used in) financing activities	(104,466)	(81,186)
Net increase (decrease) in cash and cash equivalents	0	0
CASH AND CASH EQUIVALENTS, beginning of year	0	0
CASH AND CASH EQUIVALENTS, end of period	$ 0	$ 0

Condensed Consolidating Finan89

Condensed Consolidating Financial Information - Narrative (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2014	Dec. 31, 2014
Parent
Condensed Financial Statements, Captions
Intercompany borrowings, adjustments	$ (382.7)
Guarantors
Condensed Financial Statements, Captions
Property, plant and equipment, net, adjustments		$ 150.4
Intercompany borrowings, adjustments	$ 382.7
Non-Guarantors
Condensed Financial Statements, Captions
Property, plant and equipment, net, adjustments		$ (150.4)

Subsequent Events - Royalty Tru

Subsequent Events - Royalty Trust Distributions (Details) - Subsequent Event $ in Thousands	Jul. 30, 2015USD ($)
Mississippian Trust I
Subsequent Event
Total Distribution	$ 8,428
Amount Distributed to Third-Party Unitholders	6,162
Permian Trust
Subsequent Event
Total Distribution	16,656
Amount Distributed to Third-Party Unitholders	16,656
Mississippian Trust II
Subsequent Event
Total Distribution	9,361
Amount Distributed to Third-Party Unitholders	7,794
Royalty Trusts
Subsequent Event
Total Distribution	34,445
Amount Distributed to Third-Party Unitholders	$ 30,612

Uncategorized Items - sd-201506

Label	Element	Value
Commodity Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	us-gaap_FairValueNetDerivativeAssetLiabilityMeasuredOnRecurringBasisWithUnobservableInputs	$ 0