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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)

☑			QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2020

OR

☐			TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from              to             

Commission File Number: 001-33784

SANDRIDGE ENERGY, INC.

(Exact name of registrant as specified in its charter)

Delaware						20-8084793
(State or other jurisdiction of incorporation or organization)						(I.R.S. Employer Identification No.)
123 Robert S. Kerr Avenue Oklahoma City, Oklahoma						73102
(Address of principal executive offices)						(Zip Code)

Registrant’s telephone number, including area code: (405) 429-5500

Former name, former address and former fiscal year, if changed since last report: Not applicable

Securities registered pursuant to Section 12(b) of the Act:

Title of each class

Trading Symbol

Name of each exchange on which registered

Common Stock, $.001 par value

SD

New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No o

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☑ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer

☐

Accelerated filer

☑

Non-accelerated filer

☐

Smaller reporting company

☑

Emerging growth company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No þ

Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Sections 12, 13, or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court. Yes ☑ No o

The number of shares outstanding of the registrant’s common stock, par value $0.001 per share, as of the close of business on July 29, 2020, was 35,814,879.

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References in this report to the “Company,” “SandRidge,” “we,” “our,” and “us” mean SandRidge Energy, Inc., including its consolidated subsidiaries and its proportionately consolidated share of each of SandRidge Mississippian Trust I and SandRidge Mississippian Trust II, (collectively, the “Royalty Trusts”).

DISCLOSURES REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q (“Quarterly Report”) of the Company includes “forward-looking statements” as defined by the SEC. These forward-looking statements may include projections and estimates concerning our capital expenditures, liquidity, capital resources and debt profile including the ability to continue as a going concern, the timing and success of specific projects, the potential impact of the COVID-19 pandemic on the Company's business, the potential impact of international negotiations on the supply and demand of oil and gas, outcomes and effects of litigation, claims and disputes, elements of our business strategy, compliance with governmental regulation of the oil and natural gas industry, including environmental regulations, acquisitions and divestitures and the potential effects on our financial condition and other statements concerning our operations, financial performance and financial condition.

Forward-looking statements are generally accompanied by words such as “estimate,” “assume,” “target,” “project,” “predict,” “believe,” “expect,” “anticipate,” “potential,” “could,” “may,” “foresee,” “plan,” “goal,” “should,” “intend” or other words that convey the uncertainty of future events or outcomes. These forward-looking statements are based on certain assumptions and analyses based on our experience and perception of historical trends, current conditions and expected future developments as well as other factors we believe are appropriate under the circumstances. Such statements are not guarantees of future performance and actual results or developments may differ materially from those projected. The Company disclaims any obligation to update or revise these forward-looking statements unless required by law, and it cautions readers not to rely on them unduly. While we consider these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties relating to, among other matters, the risks and uncertainties discussed in “Risk Factors” in Item 1A of the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2019 (the “2019 Form 10-K”) and in Item 1A of this Quarterly Report.

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SANDRIDGE ENERGY, INC. AND SUBSIDIARIES

FORM 10-Q

Quarter Ended June 30, 2020

INDEX

PART I. FINANCIAL INFORMATION

ITEM 1.

Financial Statements (Unaudited):

Condensed Consolidated Balance Sheets

4

Condensed Consolidated Statements of Operations

5

Condensed Consolidated Statement of Changes in Stockholders’ Equity

6

Condensed Consolidated Statements of Cash Flows

7

Notes to Condensed Consolidated Financial Statements

8

ITEM 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

22

ITEM 3.

Quantitative and Qualitative Disclosures About Market Risk

33

ITEM 4.

Controls and Procedures

35

PART II. OTHER INFORMATION

ITEM 1.

Legal Proceedings

36

ITEM 1A.

Risk Factors

37

ITEM 2.

Unregistered Sales of Equity Securities and Use of Proceeds

37

ITEM 3.

Defaults upon Senior Securities

38

ITEM 4.

Mine Safety Disclosures

38

ITEM 5.

Other Information

38

ITEM 6.

Exhibits

39

Signature

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PART I. Financial Information

ITEM 1. Financial Statements

SANDRIDGE ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

(In thousands, except per share data) 

			June 30, 2020						December 31, 2019
ASSETS
Current assets
Cash and cash equivalents			$	13,473					$	4,275
Restricted cash - other			1,454						1,693
Accounts receivable, net			16,608						28,644
Derivative contracts			2,004						114
Prepaid expenses			2,218						3,342
Assets held for sale			35,447						—
Other current assets			80						538
Total current assets			71,284						38,606
Oil and natural gas properties, using full cost method of accounting
Proved			1,489,793						1,484,359
Unproved			22,753						24,603
Less: accumulated depreciation, depletion and impairment			(1,335,830)						(1,129,622)
			176,716						379,340
Other property, plant and equipment, net			106,665						188,603
Other assets			766						1,140
Total assets			$	355,431					$	607,689

LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Accounts payable and accrued expenses			$	41,996					$	64,937
Current maturities of long-term debt			59,000						—
Asset retirement obligation			22,055						22,119
Liabilities held for sale			403						—
Other current liabilities			1,120						1,367
Total current liabilities			124,574						88,423
Long-term debt			—						57,500
Asset retirement obligation			52,879						52,897
Other long-term obligations			3,209						6,417
Total liabilities			180,662						205,237
Commitments and contingencies (Note 9)
Stockholders’ Equity
Common stock, $0.001 par value; 250,000 shares authorized; 35,865 issued and outstanding at June 30, 2020 and 35,772 issued and outstanding at December 31, 2019			36						36
Warrants			88,520						88,520
Additional paid-in capital			1,060,019						1,059,253
Accumulated deficit			(973,806)						(745,357)
Total stockholders’ equity			174,769						402,452
Total liabilities and stockholders’ equity			$	355,431					$	607,689

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SANDRIDGE ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(In thousands, except per share data)

																		Three Months Ended June 30,																					Six Months Ended June 30,
																		2020									2019						2020						2019
Revenues
Oil, natural gas and NGL																		$	16,448								$	75,196					$	56,587					$	148,244
Other																		207									192						397						380
Total revenues																		16,655									75,388						56,984						148,624
Expenses
Lease operating expenses																		8,698									25,076						24,340						47,855
Production, ad valorem, and other taxes																		1,854									5,877						5,053						10,957
Depreciation and depletion — oil and natural gas																		13,348									39,419						38,203						75,884
Depreciation and amortization — other																		1,739									2,986						4,373						5,929
Impairment																		201,784									—						209,754						—
General and administrative																		4,314									10,084						9,797						20,023
Restructuring expenses																		444									—						444						—
Employee termination benefits																		1,993									4,465						5,247						4,465
(Gain) loss on derivative contracts																		(2,241)									—						(12,467)						209
Other operating expense																		108									37						385						119
Total expenses																		232,041									87,944						285,129						165,441
Loss from operations																		(215,386)									(12,556)						(228,145)						(16,817)
Other income (expense)
Interest expense, net																		(447)									(702)						(1,084)						(1,287)
Other income (expense), net																		58									(26)						134						(457)
Total other expense																		(389)									(728)						(950)						(1,744)
Loss before income taxes																		(215,775)									(13,284)						(229,095)						(18,561)
Income tax expense (benefit)																		4									—						(646)						—
Net loss																		$	(215,779)								$	(13,284)					$	(228,449)					$	(18,561)
Loss per share
Basic																		$	(6.06)								$	(0.38)					$	(6.42)					$	(0.53)
Diluted																		$	(6.06)								$	(0.38)					$	(6.42)					$	(0.53)
Weighted average number of common shares outstanding
Basic																		35,611									35,356						35,581						35,339
Diluted																		35,611									35,356						35,581						35,339

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SANDRIDGE ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY (Unaudited)

(In thousands) 

						Common Stock																		Warrants																		Additional Paid-In Capital												Accumulated Deficit						Total
						Shares						Amount						Shares						Amount
Six Months Ended June 30, 2020
Balance at December 31, 2019						35,772						$	36					6,659						$	88,520					$	1,059,253											$	(745,357)					$	402,452
Stock-based compensation						—						—						—						—						185												—						185
Issuance of common stock for general unsecured claims						38						—						—						—						—												—						—
Issuance of warrants for general unsecured claims						—						—						47						—						—												—						—
Cash paid for tax withholdings on vested stock awards						—						—						—						—						(1)												—						(1)
Net loss						—						—						—						—						—												(12,670)						(12,670)
Balance at March 31, 2020						35,810						$	36					6,706						$	88,520					$	1,059,437											$	(758,027)					$	389,966
Stock-based compensation						—						—						—						—						583												—						583
Issuance of stock awards, net of cancellations						55						—						—						—						—												—						—
Cash paid for tax withholdings on vested stock awards						—						—						—						—						(1)												—						(1)
Net loss						—						—						—						—																		(215,779)						(215,779)
Balance at June 30, 2020						35,865						$	36					6,706						$	88,520					$	1,060,019											$	(973,806)					$	174,769

						Common Stock																		Warrants																		Additional Paid-In Capital												Accumulated Deficit						Total
						Shares						Amount						Shares						Amount
Six Months Ended June 30, 2019
Balance at December 31, 2018						35,687						$	36					6,604						$	88,516					$	1,055,164											$	(295,995)					$	847,721
Stock-based compensation						—						—						—						—						1,073												—						1,073
Issuance of warrants for general unsecured claims						—						—						1						2						(2)												—						—
Cumulative effect of adoption of ASU 2016-02						—						—						—						—						—												(57)						(57)
Net loss						—						—						—						—						—												(5,277)						(5,277)
Balance at March 31, 2019						35,687						$	36					6,605						$	88,518					$	1,056,235											$	(301,329)					$	843,460
Issuance of stock awards, net of cancellations						75						—						—						—						—												—						—
Stock-based compensation						—						—						—						—						2,170												—						2,170
Cash paid for whithholdings on vested stock awards						—						—						—						—						(205)												—						(205)
Net loss						—						—						—						—						—												(13,284)						(13,284)
Balance at June 30, 2019						35,762						$	36					6,605						$	88,518					$	1,058,200											$	(314,613)					$	832,141

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SANDRIDGE ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(In thousands)

			Six Months Ended June 30,
			2020						2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net loss			$	(228,449)					$	(18,561)
Adjustments to reconcile net loss to net cash provided by operating activities
Provision for doubtful accounts			283						(91)
Depreciation, depletion, and amortization			42,576						81,813
Impairment			209,754						—
Debt issuance costs amortization			318						238
Write off of debt issuance costs			—						142
(Gain) loss on derivative contracts			(12,467)						209
Cash received on settlement of derivative contracts			10,577						5,078
Loss (gain) on sale of assets			78						—
Stock-based compensation			749						3,104
Other			68						(57)
Changes in operating assets and liabilities			(10,025)						(9,402)
Net cash provided by operating activities			13,462						62,473
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures for property, plant and equipment			(6,814)						(123,676)
Acquisition of assets			—						236
Proceeds from sale of assets			1,506						852
Net cash used in investing activities			(5,308)						(122,588)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from borrowings			39,000						112,596
Repayments of borrowings			(37,500)						(60,596)
Reduction of financing lease liability			(694)						(635)
Debt issuance costs			—						(901)
Cash paid for tax withholdings on vested stock awards			(1)						(205)
Net cash provided by financing activities			805						50,259
NET INCREASE (DECREASE) IN CASH, CASH EQUIVALENTS and RESTRICTED CASH			8,959						(9,856)
CASH, CASH EQUIVALENTS and RESTRICTED CASH, beginning of year			5,968						19,645
CASH, CASH EQUIVALENTS and RESTRICTED CASH, end of period			$	14,927					$	9,789
Supplemental Disclosure of Cash Flow Information
Cash paid for interest, net of amounts capitalized			$	(812)					$	(949)
Cash received for income taxes			$	616					$	—
Supplemental Disclosure of Noncash Investing and Financing Activities
Purchase of PP&E in accounts payable			$	704					$	17,224
Right-of-use assets obtained in exchange for financing lease obligations			$	67					$	2,655

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SANDRIDGE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Basis of Presentation

Nature of Business. SandRidge Energy, Inc. is an oil and natural gas acquisition, development and production company headquartered in Oklahoma City, Oklahoma with a principal focus on developing and producing hydrocarbon resources in the United States.

Principles of Consolidation. The consolidated financial statements include the accounts of the Company and its wholly owned or majority owned subsidiaries, including its proportionate share of the Royalty Trusts. All intercompany accounts and transactions have been eliminated in consolidation.

Interim Financial Statements. The accompanying unaudited condensed consolidated financial statements and notes should be read in conjunction with the audited financial statements and notes contained in the Company’s 2019 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 financial statements include all adjustments, which consist of normal recurring adjustments unless otherwise disclosed, necessary to fairly state the Company’s unaudited condensed consolidated financial statements.  

Significant Accounting Policies. The unaudited condensed consolidated financial statements were prepared in accordance with the accounting policies stated in the 2019 Form 10-K as well as the items noted below.

Use of Estimates. The preparation of the 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; impairment tests of long-lived assets; the carrying value of unproved oil and natural gas properties and other property, plant and equipment; depreciation, depletion and amortization; asset retirement obligations; determinations of significant alterations to the full cost pool and related estimates of fair value used to allocate the full cost pool net book value to divested properties, as necessary; valuation allowances for deferred tax assets; income taxes; valuation of derivative instruments; contingencies; and accrued revenue and related receivables. Although management believes the estimates used in the areas noted above are reasonable, actual results could differ significantly.

Going Concern Consideration. The accompanying condensed consolidated financial statements are prepared in accordance with generally accepted accounting principles applicable to a going concern, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business.

The Company currently has a borrowing base of $75.0 million under its credit facility and as of June 30, 2020 the Company had $59.0 million outstanding under its credit facility and $4.3 million in outstanding letters of credit, which reduces availability under the restated credit facility on a dollar-for-dollar basis. This leaves an additional $11.7 million available to be borrowed under the credit facility.

The Company is under contract to sell the Company's corporate headquarters building. In addition, management has begun communications with its lenders, and other capital providers, to refinance the balance of the outstanding credit facility, which matures on April 1, 2021. The due diligence period for the building sale has expired, and the sale is expected to close during the third quarter of 2020. In addition to using cash flows from operations, management's plans include repaying the outstanding credit facility borrowings, at or before maturity, using the proceeds from the contracted sale of the building, refinancing the credit facility, or both.

In its evaluation of going concern, in accordance with ASC 205-40, management evaluated relevant conditions and events regarding the Company's ability to meet future obligations without taking into consideration management's plans to refinance its existing debt or sell its corporate headquarters. Based on that evaluation, the Company currently does not project that it will have sufficient cash on hand or available liquidity to repay the outstanding credit facility balance on the maturity date, which gives rise to substantial doubt about the Company’s ability to continue as a going concern. The Company’s plans discussed above, however, are probable of being achieved and would alleviate substantial doubt about its ability to continue as a going concern.

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SANDRIDGE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED

(Unaudited)

Recently Adopted Accounting Pronouncements. ASU 2016-13 - In March 2016, the FASB issued ASU 2016-13, “Financial Instruments —Credit Losses (Topic 326) Measurement of Credit Losses on Financial Instruments,” which changes how entities will measure credit losses for most financial assets and certain other instruments that are not measured at fair value through net income. The standard replaced the previously required incurred loss approach with an expected loss model for instruments measured at amortized cost. The company adopted this ASU on January 1, 2020 using a modified retrospective approach; however, the impact was not material upon adoption.

Recent Accounting Pronouncements Not Yet Adopted. ASU 2020-04 - In March 2020, FASB issued ASU No. 2020-04, Reference Rate Reform (Topic 848), to facilitate the effects of reference rate reform on financial reporting. This ASU provides optional practical expedients and exceptions for applying US GAAP provisions to contracts, hedging relationships, and other transactions that reference LIBOR, or other reference rates expected to be discontinued because of reference rate reform, if certain criteria are met. The provisions of this ASU do not apply to contract modifications made and hedging transactions entered into or evaluated after December 31, 2022, except for hedging relationships existing as of December 31, 2022, that an entity has elected certain optional expedients for and that are retained through the end of the hedging relationship. The amendments in ASU 2020-04 are effective, for all entities, as of March 12, 2020 through December 31, 2022. The Company is currently reviewing the potential impact of the upcoming LIBOR reference rate change on its current contracts and hedging relationships and will determine the applicable provisions of ASU 2020-04.

ASU 2019-12 - In December 2019, the FASB issued ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes,” which simplifies various aspects of accounting for income taxes, including requirements related to hybrid tax regimes, the tax basis step-up in goodwill obtained in a transaction that is not a business combination, separate financial statements of entities not subject to tax, the intraperiod tax allocation exception to the incremental approach, ownership changes in investments, interim-period accounting for enacted changes in tax laws, and year-to-date loss limitation in interim-period tax accounting. The standard is effective for interim and annual periods beginning after December 15, 2020, with early adoption permitted, and will be applied on a prospective basis. The Company is currently evaluating the effect the guidance will have on its consolidated financial statements.

2. Fair Value Measurements

The Company measures and reports certain assets and liabilities on a fair value basis and has classified and disclosed its fair value measurements using the levels of the fair value hierarchy noted below. The carrying values of cash, restricted cash, accounts receivable, prepaid expenses, certain other current assets and other assets, accounts payable and accrued expenses, other current liabilities and other long-term obligations included in the unaudited condensed consolidated balance sheets approximated fair value at June 30, 2020, and December 31, 2019. Additionally, the carrying amount of debt associated with borrowings outstanding under the credit facility approximates fair value as borrowings bear interest at variable rates. As a result, these financial assets and liabilities are not discussed below. Further, the fair value of our assets held for sale is calculated using Level 2 inputs, which is discussed in Note 6. No other adjustments to fair value were required for other property, plant and equipment for the three and six-month periods ended June 30, 2020 and 2019.

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 from 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

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SANDRIDGE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED

(Unaudited)

basis. The Company had assets classified in Level 2 of the hierarchy as of June 30, 2020 and December 31, 2019, as described below.

Level 2 Fair Value Measurements

Commodity Derivative Contracts. The fair values of the Company’s oil and natural gas fixed price swaps are based upon inputs that are either readily available in the public market, such as oil and natural gas futures prices, volatility factors and discount rates, or can be corroborated from active markets. Fair value is determined through the use of a discounted cash flow model or option pricing model using the applicable inputs discussed above. The Company applies a weighted average credit default risk rating factor for its counterparties or gives effect to its credit default risk rating, as applicable, in determining the fair value of these derivative contracts. Credit default risk ratings are based on current published credit default swap rates.

Fair Value - Recurring Measurement Basis

The following tables summarize the Company’s assets measured at fair value on a recurring basis by the fair value hierarchy (in thousands):

June 30, 2020

			Fair Value Measurements																														Netting(1)						Assets/Liabilities at Fair Value
			Level 1						Level 2						Level 3
Assets
Commodity derivative contracts			$	—					$	2,004					$	—					$	—					$	2,004
			$	—					$	2,004					$	—					$	—					$	2,004

December 31, 2019

			Fair Value Measurements																														Netting(1)						Assets/Liabilities at Fair Value
			Level 1						Level 2						Level 3
Assets
Commodity derivative contracts			$	—					$	114					$	—					$	—					$	114
			$	—					$	114					$	—					$	—					$	114

____________________

(1) Represents the effect of netting assets and liabilities for counterparties with which the right of offset exists.

Transfers. The Company did not have any transfers between Level 1, Level 2 or Level 3 fair value measurements during the three and six-month periods ended June 30, 2020 and 2019.

3. Derivatives

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. On occasion, the Company has attempted to manage this risk on a portion of its forecasted oil or natural gas production sales through the use of commodity derivative contracts. The Company has not designated any of its derivative contracts as hedges for accounting purposes. All derivative contracts are recorded at fair value with changes in derivative contract fair values recognized as gain or loss on derivative contracts in the condensed consolidated statements of operations. None of the Company’s commodity derivative contracts may be terminated prior to contractual maturity solely as a result of a downgrade in the credit rating of a party to the contract. Commodity derivative contracts are settled on a monthly basis, and the commodity derivative contract valuations are adjusted to the mark-to-market valuation on a quarterly basis.

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SANDRIDGE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED

(Unaudited)

The following table summarizes derivative activity for the three and six-month periods ended June 30, 2020, and 2019 (in thousands):

			Three Months Ended June 30,																		Six Months Ended June 30,
			2020						2019						2020						2019
(Gain) loss on commodity derivative contracts			$	(2,241)					$	—					$	(12,467)					$	209
Cash received on settlements			$	6,490					$	—					$	10,577					$	5,078

Master Netting Agreements and the Right of Offset. The Company has master netting agreements with all of its commodity derivative counterparties and has presented its derivative assets and liabilities with the same counterparty on a net basis in the unaudited condensed consolidated balance sheets. As a result of the netting provisions, the Company's maximum amount of loss under commodity derivative transactions due to credit risk is limited to the net amounts due from its counterparties. As of June 30, 2020, the counterparties to the Company's open commodity derivative contracts consisted of two financial institutions, both of which are also lenders under the Company's credit facility. The Company is not required to post additional collateral under its commodity derivative contracts as all of the counterparties to the Company’s commodity derivative contracts share in the collateral supporting the Company’s credit facility.

The following table summarizes (i) the Company's commodity derivative contracts on a gross basis, (ii) the effects of netting assets and liabilities for which the right of offset exists based on master netting arrangements and (iii) for the Company’s net derivative liability positions, the applicable portion of shared collateral under the credit facility as of June 30, 2020 and December 31, 2019 (in thousands):

June 30, 2020

						Gross Amounts						Gross Amounts Offset						Amounts Net of Offset						Financial Collateral						Net Amount
Assets
Derivative contracts - current						$	2,004					$	—					$	2,004					$	—					$	2,004
Total						$	2,004					$	—					$	2,004					$	—					$	2,004

December 31, 2019

						Gross Amounts						Gross Amounts Offset						Amounts Net of Offset						Financial Collateral						Net Amount
Assets
Derivative contracts - current						$	114					$	—					$	114					$	—					$	114
Total						$	114					$	—					$	114					$	—					$	114

At June 30, 2020, the Company's open derivative contracts consisted of natural gas commodity derivative contracts under which we will receive a fixed price for the contract and pay a floating market price to the counterparty over a specified period for a contracted volume. These commodity derivative contracts consisted of the following:

						Notional (MMBtu)						Weighted Average Fixed Price per Unit
Natural Gas Price Swaps: July 2020 - October 2020						4,920,000						$	2.14

Further, subsequent to June 30, 2020, in July 2020, the Company entered into derivative contracts consisting of natural gas commodity derivative contracts under which we will receive a fixed price for the contract and pay a floating market price to the counterparty over a specified period for a contracted volume. These commodity derivative contracts consisted of the following:

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			Notional (MMBtu)						Weighted Average Fixed Price per Unit
Natural Gas Price Swaps: November 2020 - December 2020			2,135,000						$	2.54
Natural Gas Price Swaps: January 2021 - December 2021			10,950,000						$	2.61

Because we have not designated any of our derivative contracts as hedges for accounting purposes, changes in the fair value of our derivative contracts are recognized as gains and losses in current period earnings. As a result, our current period earnings may be significantly affected by changes in the fair value of our commodity derivative contracts. Changes in fair value are principally measured based on a comparison of future prices to the contract price at the period-end.

Fair Value of Derivatives 

The following table presents the fair value of the Company’s derivative contracts as of June 30, 2020 and December 31, 2019, on a gross basis without regard to same counterparty netting (in thousands):

Type of Contract						Balance Sheet Classification						June 30, 2020						December 31, 2019
Derivative assets
Oil price swaps						Derivative contracts-current						$	—					$	114
Natural gas price swaps						Derivative contracts-current						2,004						—
Total net derivative contracts																		$	2,004					$	114

See Note 2 for additional discussion of the fair value measurement of the Company’s derivative contracts.

4. Property, Plant and Equipment

Property, plant and equipment consists of the following (in thousands): 

			June 30, 2020						December 31, 2019
Oil and natural gas properties
Proved			$	1,489,793					$	1,484,359
Unproved			22,753						24,603
Total oil and natural gas properties			1,512,546						1,508,962
Less accumulated depreciation, depletion and impairment			(1,335,830)						(1,129,622)
Net oil and natural gas properties			176,716						379,340
Land			200						4,400
Electrical infrastructure			121,818						126,482
Other non-oil and natural gas equipment			1,934						12,665
Buildings and structures			3,603						77,148
Financing leases			1,552						2,109
Total			129,107						222,804
Less accumulated depreciation and amortization			(22,442)						(34,201)
Other property, plant and equipment, net			106,665						188,603
Total property, plant and equipment, net			$	283,381					$	567,943

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See Note 5 for discussion of impairment of property, plant and equipment, and Note 6 for discussion of the pending divestiture of the Company's headquarters in Oklahoma City, OK, which is included in buildings and structures in the table above as of December 31, 2019.

5. Impairment

The Company assesses the need to impair its oil and gas properties during its quarterly full cost pool ceiling limitation calculation. The Company analyzes various property, plant and equipment for impairment when certain triggering events occur by comparing the carrying values of the assets to their estimated fair values. The full cost pool ceiling limitation and estimated fair values of other assets were determined in accordance with the policies discussed in Note 1.

In the three-month period ended June 30, 2020, we recorded a total impairment charge of $201.8 million, which included a full cost ceiling limitation impairment charge of $163.8 million, and an impairment charge of $38.0 million to write down the value of the Company's office headquarters, classified as assets held for sale, to its estimated fair value less estimated costs to sell the building.

In the six-month period ended June 30, 2020, we recorded a total impairment charge of $209.8 million, which included a full cost ceiling limitation impairment charge of $171.8 million, and an impairment charge of $38.0 million to write down the value of the Company's office headquarters, classified as assets held for sale, to its estimated fair value less estimated costs to sell the building.

The ceiling limitation impairment charges recorded in the six-month period ended June 30, 2020 resulted from various factors, including a decrease in proved reserve value driven by a significant decline in the trailing twelve-month weighted average oil and natural gas prices in the first and second quarters of 2020. No impairment was recorded for the three and six-month period ended June 30, 2019. Impairment charges for the Company's office headquarters is further discussed in Note 6.

Calculation of the full cost ceiling test is based on, among other factors, average prices for the trailing twelve-month period determined by reference to the first-day-of-the-month index prices ("SEC prices") as adjusted for price differentials and other contractual arrangements. The SEC prices utilized in the calculation of proved reserves included in the full cost ceiling test at June 30, 2020 were $47.17 per barrel of oil and $2.07 per Mcf of natural gas, before price differential adjustments.

6. Assets and Liabilities Held for Sale

In May 2020, the Company entered into an agreement for the sale of its corporate headquarters building located in Oklahoma City, OK. The Company expects the sale to be completed in the third quarter of 2020 after a due diligence period and result in proceeds of approximately $35.5 million. The agreement includes an earnest money provision to be provided by the buyer in an amount of $0.1 million.

In accordance with the applicable accounting guidance, FASB ASC 360-10-45-9, the Company reclassified its corporate headquarters building net carrying amount from Other property, plant and equipment, net, to Assets held for sale on the Condensed Consolidated Balance Sheets at June 30, 2020. The Company also reclassified the liabilities associated with the corporate headquarters building from Accounts payable and accrued expenses to Liabilities held for sale on the Condensed Consolidated Balance Sheets at June 30, 2020. Further we recorded an impairment charge of $38.0 million in the three-month period ended June 30, 2020 to write down the net carrying amount of the office headquarters building assets to their estimated fair value less estimated costs to sell the building. The impairment charge is included in the Impairment line item of the Condensed Consolidated Statements of Operations for the three and six-month periods ended June 30, 2020. No impairment charges were recorded for the corporate headquarters building assets in the three and six-month period ended June 30, 2019. Prior to the sale of the building, the carrying value of the building was assessed for impairment using undiscounted cash flow measures as prescribed under ASC 360-10-35, rather than fair value.

The table below sets forth an analysis of the Company's assets and liabilities held for sale at June 30, 2020 (in thousands):

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Assets held for sale at June 30, 2020:
Net carrying amount before impairment						$	73,447
Less: asset write-down to fair value			$	(37,947)
Less: estimated cost of sale			(53)
Subtotal impairment charges						(38,000)
Assets held for sale balance at June 30, 2020						$	35,447
Liabilities held for sale at June 30, 2020:
Accounts payable						$	6
Accrued expenses						397
Liabilities held for sale balance at June 30, 2020						$	403

7. Accounts Payable and Accrued Expenses

Accounts payable and accrued expenses consist of the following (in thousands):

			June 30, 2020									December 31, 2019
Accounts payable and other accrued expenses			$	17,469								$	29,423
Production payable			12,427									22,530
Payroll and benefits			5,183									7,021
Taxes payable			6,288									4,988
Drilling advances			479									514
Accrued interest			150									461
Total accounts payable and accrued expenses			$	41,996								$	64,937

8. Debt

Credit Facility.

As of June 30, 2020, the Company had a borrowing base of $75.0 million under its credit facility, with $59.0 million outstanding and $4.3 million in outstanding letters of credit, which reduces availability under the credit facility on a dollar-for-dollar basis. This leaves $11.7 million available to be drawn under the credit facility. The next borrowing base redetermination is expected to occur during the fourth quarter of 2020. The credit facility matures on April 1, 2021.

The interest rate on outstanding borrowings under the credit facility was determined by a pricing grid tied to borrowing base utilization of (a) LIBOR plus an applicable margin that varies from 2.00% to 3.00% per annum, or (b) the base rate plus an applicable margin that varies from 1.00% to 2.00% per annum. Interest on base rate borrowings is payable quarterly in arrears and interest on LIBOR borrowings is payable every one, two, three or six months, at the election of the Company. Quarterly, the Company pays commitment fees assessed at annual rates of 0.50% on any available portion of the credit facility. During the three and six-month period ended June 30, 2020, the weighted average interest rate paid for borrowings outstanding under the credit facility was approximately 3.0% and 3.4%, respectively.

The Company has the right to prepay loans under the credit facility at any time without a prepayment penalty, other than customary “breakage” costs with respect to LIBOR loans.

The credit facility is secured by (i) first-priority mortgages on at least 85% of the PV-9 valuation of all proved reserves included in the most recently delivered reserve report of the Company, (ii) a first-priority perfected pledge of substantially all of the capital stock owned by each credit party and equity interests in the Royalty Trusts that are owned by a credit party and (iii) a

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first-priority perfected security interest in substantially all the cash, cash equivalents, deposits, securities and other similar accounts, and other tangible and intangible assets of the credit parties (including but not limited to as-extracted collateral, accounts receivable, inventory, equipment, general intangibles, investment property, intellectual property, real property and the proceeds of the foregoing).

The credit facility includes events of default and certain customary affirmative and negative covenants. The Company must also continue to maintain certain financial covenants including (i) a maximum consolidated total net leverage ratio, measured as of the end of any fiscal quarter, of no greater than 3.50 to 1.00 and (ii) a minimum consolidated interest coverage ratio, measured as of the end of any fiscal quarter, of no less than 2.25 to 1.00. As of June 30, 2020, the Company was in compliance with all applicable covenants and had a consolidated total net leverage ratio of 0.5 and consolidated interest coverage ratio of 27.93.

9. Commitments and Contingencies

Legal Proceedings. As previously disclosed, on May 16, 2016, the Company and certain of its direct and indirect subsidiaries (collectively, the “Debtors”) filed voluntary petitions for reorganization under Chapter 11 of the United States Bankruptcy Code in the United States Bankruptcy Court for the Southern District of Texas (the “Bankruptcy Court”). The Bankruptcy Court confirmed the joint plan of organization (the “Plan”) of the Debtors on September 9, 2016, and the Debtors subsequently emerged from bankruptcy on October 4, 2016.

Pursuant to the Plan, claims against the Company were discharged without recovery in each of the following consolidated cases (the “Cases”):

•In re SandRidge Energy, Inc. Securities Litigation, Case No. 5:12-cv-01341-LRW, USDC, Western District of Oklahoma; and

•Ivan Nibur, Lawrence Ross, Jase Luna, Matthew Willenbucher, and the Duane & Virginia Lanier Trust v. SandRidge Mississippian Trust I, et al., Case No. 5:15-cv-00634-SLP, USDC, Western District of Oklahoma

The lead plaintiffs in both In re SandRidge Energy, Inc. Securities Litigation and Lanier Trust assert claims on behalf of themselves and (i) in In re SandRidge Energy, Inc. Securities Litigation, a class of all purchasers of SandRidge common stock from February 24, 2011 and November 8, 2012 under Sections 10(b) and 20(a) of the Securities Exchange Act of 1934, and Rule 10b-5 promulgated thereunder, and (ii) in Lanier Trust, a putative class of purchasers of SandRidge Mississippian Trust I and SandRidge Mississippian Trust II common units between April 7, 2011 and November 8, 2012 under Sections 11, 12(a)(2), and 15 of the Securities Act of 1933 and Sections 10(b) and 20(a) of the Securities Exchange Act of 1934, and Rule 10b-5 promulgated thereunder, both based on allegations that defendants, which include certain former officers of the Company and the SandRidge Mississippian Trust I, made misrepresentations or omissions concerning various topics including the performance of wells operated by the Company in the Mississippian region.

Discovery in each of the Cases closed on June 19, 2019. Following a hearing on class certification in each of the Cases on September 6, 2019, the court granted class certification in In re SandRidge Energy, Inc. Securities Litigation on September 30, 2019. The motion for class certification in Lanier Trust remains pending. On April 2, 2020, the individual defendants and SandRidge Mississippian Trust I filed motions for summary judgment seeking the dismissal of all claims asserted against them in the Lanier Trust matter. On the same date, the individual defendants filed motions for summary judgment seeking the dismissal of all claims asserted against them In re SandRidge Energy, Inc. Securities Litigation. The motions remain pending.

In each of the Cases, lead plaintiffs seek to recover unspecified damages, interest, costs and expenses incurred in the litigation on behalf of themselves and class members. Although the claims against the Company in each Case have been discharged pursuant to the Plan, the Company remains a nominal defendant in each of the Cases to the extent necessary to allow recovery from applicable insurance policies or proceeds. In addition, the Company owes indemnity obligations and/or the obligation to advance legal fees, to certain former officers who remain as defendants in each action. The Company may also be contractually obligated to indemnify the SandRidge Mississippian Trust I against losses, claims, damages, liabilities and expenses, including reasonable costs of investigation and attorney’s fees and expenses, arising out of the Cases, and such indemnification is not covered by insurance.

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In light of the status of the Cases, and the facts, circumstances and legal theories relating thereto, the Company is not able to determine the likelihood of an outcome in either case or provide an estimate of any reasonably possible loss or range of possible loss related thereto. However, considering the erosion of insurance coverage available to the Company, such losses, if incurred, could be material. The Company has not established any liabilities relating to the Cases and believes that the plaintiffs’ claims are without merit. The Company intends to continue to vigorously defend against the Cases in its capacity as a nominal defendant.

In addition to the matters described above, the Company is involved in various lawsuits, claims and proceedings which are being handled and defended by the Company in the ordinary course of business.

10. Income Taxes

For each interim reporting period, the Company estimates 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.

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 a full valuation allowance against its net deferred tax asset at June 30, 2020. As a result, the Company had no federal or state income tax expense and recorded an insignificant income tax benefit for the six-month period ended June 30, 2020. The benefit is related to previously sequestered alternative minimum tax (AMT) refund amounts released to the Company during the current quarter. The Company has no remaining AMT credits to be refunded. The Company had no federal or state income tax expense or benefit for the six-month period ended June 30, 2019.

Internal Revenue Code (“IRC”) Section 382 addresses company ownership changes and specifically limits the utilization of certain deductions and other tax attributes on an annual basis following an ownership change. As a result of the Chapter 11 reorganization and related transactions, the Company experienced an ownership change within the meaning of IRC Section 382 during 2016 that subjected certain of the Company’s tax attributes, including net operating losses ("NOLs"), to an IRC Section 382 limitation. This limitation has not resulted in cash taxes for any period subsequent to the ownership change. Since the 2016 ownership change, the Company has generated additional NOLs and other tax attributes that are not currently subject to an IRC Section 382 limitation. The Company's ability to use NOLs and other tax attributes to reduce taxable income and income taxes could be materially impacted by a future IRC 382 ownership change. Future transactions involving the Company's stock, including those outside of the Company's control, could cause an IRC 382 ownership change resulting in a limitation on tax attributes currently not limited and a more restrictive limitation on tax attributes currently subject to the previous IRC 382 limitation. On July 1, 2020, the Company entered into a Tax Benefits Preservation Plan (defined below) to protect shareholder value against a possible limitation on the Company's ability to use its NOLs. See Note 15 for more information.

The Company’s only taxing jurisdiction is the United States (federal and state). The Company’s tax years 2016 to present remain open for federal examination. Additionally, tax years 2005 through 2015 remain subject to examination for 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.

On March 27, 2020, the President of the United States signed into law the Coronavirus Aid, Relief, and Economic Security (“CARES”) Act. The CARES Act provides relief to corporate taxpayers by permitting a five year carryback of 2018-2020 NOLs, removing the 80% limitation on the carryback of those NOLs, increasing the Section 163(j) 30% limitation on interest expense deductibility to 50% of adjusted taxable income for 2019 and 2020, and accelerates refunds for minimum tax credit carryforwards, along with a few other provisions. During the six months ended June 30, 2020, no material adjustments were made to provision amounts recorded as a result of the enactment of the CARES Act.

Subsequent to June 30, 2020, in July 2020, the U.S. Treasury Department released final and proposed regulations on IRC Section 163(j) which limits business interest expense deductions. These regulations apply to tax years beginning January 1, 2021. However, taxpayers may choose to apply these regulations to tax years beginning after December 31, 2017. The

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Company is currently in the process of evaluating the effect of these regulations on its consolidated financial statements and related disclosures.

        

11. Equity

Common Stock, Performance Share Units, and Stock Options. At June 30, 2020, the Company had approximately 35.9 million shares of common stock, par value $0.001 per share, issued and outstanding. Further, at June 30, 2020, the Company had approximately 0.2 million shares of unvested restricted stock awards, 1.0 million shares of unvested restricted stock units, 0.1 million unvested stock options, and 0.1 million unvested performance share units.

Warrants. The Company has issued approximately 4.7 million Series A warrants and 2.0 million Series B warrants that are exercisable until October 4, 2022 for one share of common stock per warrant at initial exercise prices of $41.34 and $42.03 per share, respectively, subject to adjustments pursuant to the terms of the warrants, to certain holders of general unsecured claims as defined in the Plan. The warrants contain customary anti-dilution adjustments in the event of any stock split, reverse stock split, reclassification, stock dividend or other distributions. 

12. Revenues

The following table disaggregates the Company’s revenue by source for the three and six-month periods ended June 30, 2020 and 2019:

			Three Months Ended June 30,																		Six Months Ended June 30,
			2020						2019						2020						2019
			(In thousands)
Oil			$	11,554					$	55,615					$	40,208					$	98,774
NGL			1,591						9,413						7,525						22,524
Natural gas			3,303						10,168						8,854						26,946
Other			207						192						397						380
Total revenues			$	16,655					$	75,388					$	56,984					$	148,624

Oil, natural gas and NGL revenues. A majority of the Company’s revenues come from sales of oil, natural gas and NGLs and are recorded at a point in time when control of the oil, natural gas and NGL production passes to the customer at the inlet of the processing plant or pipeline, or the delivery point for onloading to a delivery truck. As the Company’s customers obtain control of the production prior to selling it to other end customers, the Company presents its revenues on a net basis, rather than on a gross basis.

Pricing for the Company’s oil, natural gas and NGL contracts is variable and is based on either an index price, net of deductions, or a percentage of the sales price obtained by the customer, which is also based on index prices. The transaction price is allocated on a pro-rata basis to each unit of oil, natural gas or NGL sold based on the terms of the contract. Oil, natural gas and NGL revenues are also recorded net of royalties, discounts and allowances, and transportation costs, as applicable. Taxes assessed by governmental authorities on oil, natural gas and NGL sales are presented separately from revenues and are included in production, ad valorem, and other tax expense in the consolidated statements of operations.

Revenues Receivable. The Company records an asset in accounts receivable, net on its consolidated balance sheet for revenues receivable from contracts with customers at the end of each period. Pricing for revenues receivable is estimated using current month crude oil, natural gas and NGL prices, net of deductions. Revenues receivable are typically collected the month after the Company delivers the related production to its customers. As of June 30, 2020, and December 31, 2019, the Company had revenues receivable of $11.0 million and $22.3 million, respectively, and did not record any bad debt expense on revenues receivable during the three and six-month periods ended June 30, 2020 and 2019.

13. Employee Termination Benefits

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Certain employees received termination benefits including cash severance and accelerated share-based compensation upon separation of service from the Company as a result of a reduction in workforce in the three and six-month period ended June 30, 2020 and 2019. The following tables presents a summary of employee termination benefits for the three and six-month periods ended June 30, 2020 and 2019 (in thousands):

						Cash						Share-Based Compensation (1)						Number of Shares						Total Employee Termination Benefits
Three Months Ended June 30, 2020
Executive Employee Termination Benefits						$	1					$	—					—						$	1
Other Employee Termination Benefits						1,992						—						—						1,992
						$	1,993					$	—					—						$	1,993
Three Months Ended June 30, 2019
Executive Employee Termination Benefits						$	877					$	478					37						$	1,355
Other Employee Termination Benefits						2,609						501						44						3,110
						$	3,486					$	979					81						$	4,465
Six Months Ended June 30, 2020
Executive Employee Termination Benefits						$	4					$	—					$	—					$	4
Other Employee Termination Benefits						5,203						40						4						5,243
						$	5,207					$	40					$	4					$	5,247
Six Months Ended June 30, 2019
Executive Employee Termination Benefits						$	877					$	478					37						$	1,355
Other Employee Termination Benefits						2,609						501						44						3,110
						$	3,486					$	979					81						$	4,465

____________________

(1) Share-based compensation recognized in connection with the accelerated vesting of restricted stock awards due to the reduction in workforce in the three and six-month period ended June 30, 2020 and 2019 and reflects the remaining unrecognized compensation expense associated with these awards at the date of termination. The unrecognized compensation expense was calculated using the grant date fair value for restricted stock awards.

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14. Loss per Share

The following table summarizes the calculation of weighted average common shares outstanding used in the computation of diluted (loss) earnings per share:

			Net (Loss) Earnings						Weighted Average Shares						(Loss) Earnings Per Share
			(In thousands, except per share amounts)
Three Months Ended June 30, 2020
Basic loss per share			$	(215,779)					35,611						$	(6.06)
Effect of dilutive securities
Restricted stock awards(1)			—						—
Performance share units(1)			—						—
Warrants(1)			—						—
Stock options(1)			—						—
Diluted loss per share			$	(215,779)					35,611						$	(6.06)
Three Months Ended June 30, 2019
Basic loss per share			$	(13,284)					35,356						$	(0.38)
Effect of dilutive securities
Restricted stock awards(1)			—						—
Performance share units(1)			—						—
Warrants(1)			—						—
Stock options(1)			—						—
Diluted earnings per share			$	(13,284)					35,356						$	(0.38)
Six Months Ended June 30, 2020
Basic loss per share			$	(228,449)					35,581						$	(6.42)
Effect of dilutive securities
Restricted stock awards(1)			—						—
Performance share units(1)			—						—
Warrants(1)			—						—
Stock options(1)			—						—
Diluted loss per share			$	(228,449)					35,581						$	(6.42)
Six Months Ended June 30, 2019
Basic loss per share			$	(18,561)					35,339						$	(0.53)
Effect of dilutive securities
Restricted stock awards(1)			—						—
Performance share units(1)			—						—
Warrants(1)			—						—
Diluted loss per share			$	(18,561)					35,339						$	(0.53)

____________________

(1) No incremental shares of potentially dilutive restricted stock awards, performance share units, warrants or stock options were included for the three and six-month periods ended June 30, 2020 and 2019, as their effect was antidilutive under the treasury stock method.

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15. Subsequent Events

The Tax Benefits Preservation Plan

On July 1, 2020, the board of directors (the “Board”) of the Company declared a dividend distribution of one right (a “Right”) for each outstanding share of common stock, par value $0.001 per share to stockholders of record at the close of business on July 13, 2020 (the “Record Date”). Each Right entitles its holder, under the circumstances described below, to purchase from the Company one one-thousandth of a share of Series A Junior Participating Preferred Stock of the Company, par value $0.001 per share (the “Preferred Stock”), at an exercise price of $5.00 per Right, subject to adjustment. The description and terms of the Rights are set forth in the tax benefits preservation plan (the “Tax Benefits Preservation Plan”), dated as of July 1, 2020, between the Company and American Stock Transfer & Trust Company, LLC, as rights agent (and any successor rights agent, the “Rights Agent”).

The Company adopted the Tax Benefits Preservation Plan in order to protect shareholder value against a possible limitation on the Company’s ability to use its NOLs and certain other tax benefits to reduce potential future U.S. federal income tax obligations. The NOLs are a valuable asset to the Company, which may inure to the benefit of the Company and its stockholders. However, if the Company experiences an “ownership change,” as defined in Section 382 of the Internal Revenue Code of 1986, as amended (the “Code”), its ability to fully utilize the NOLs and certain other tax benefits will be substantially limited and the timing of the usage of the NOLs and such other benefits could be substantially delayed, which could significantly impair the value of those assets. Generally, an “ownership change” occurs if the percentage of the Company’s stock owned by one or more of its “five-percent shareholders” (as such term is defined in Section 382 of the Code) increases by more than 50 percentage points over the lowest percentage of stock owned by such stockholder or stockholders at any time over a three-year period. The Tax Benefits Preservation Plan is intended to prevent against such an “ownership change” by deterring any person or group from acquiring beneficial ownership of 4.9% or more of the Company’s securities.

Officers and Directors of the Company

Effective July 1, 2020, the Board appointed Mr. Salah Gamoudi as the Company’s Chief Financial Officer and Chief Accounting Officer. Mr. Gamoudi, age 34, most recently served as the Company’s Vice President of Accounting and Finance beginning April 27, 2020. Prior to joining the Company, Mr. Gamoudi served as Vice President and Chief Accounting Officer at Jones Energy, Inc. from October 2018 to April 2020. Jones Energy, Inc. filed for protection under Chapter 11 of the U.S. Bankruptcy Code on April 14, 2019. Immediately before serving as Vice President and Chief Accounting Officer at Jones Energy, Inc., Mr. Gamoudi served as Chief Accounting Officer and Controller of Remora Petroleum, L.P. from 2017 to 2018. From 2015 to 2017, he served as Corporate Controller of Glacier Oil & Gas and its predecessor company, Miller Energy Resources, Inc. (“Miller Energy”). Miller Energy filed for protection under Chapter 11 of the U.S. Bankruptcy Code on October 1, 2015. From 2013 to 2015, he served as SOX and Internal Audit Manager of LRR Energy, L.P. and Lime Rock Resources. Prior to that, he served as an auditor for Deloitte & Touche LLP and for Ernst & Young LLP. Mr. Gamoudi has a Bachelor of Arts in Accounting from Portland State University and is a Certified Public Accountant.

Consistent with his employment letter dated April 24, 2020, effective July 29, 2020, the Board of the Company, upon the recommendation of the Board’s Nominating and Governance Committee, appointed Mr. Carl F. Giesler, Jr., the Company’s President and Chief Executive Officer, to serve as a member of the Board.

Prior to joining the Company, Mr. Giesler served as the Chief Executive Officer and a Director at Jones Energy, Inc. from July 2018 through January 2020. Jones Energy, Inc. filed for protection under Chapter 11 of the U.S. Bankruptcy Code on April 14, 2019. Mr. Giesler previously served as the Chief Executive Officer and a Director of Glacier Oil & Gas Corp. and its predecessor company, Miller Energy Resources, Inc. (“Miller Energy”), from September 2014 to July 2018. Miller Energy filed for protection under Chapter 11 of the U.S. Bankruptcy Code on October 1, 2015. Immediately prior to joining Glacier Oil & Gas Corp., Mr. Giesler served as a Managing Director with Harbinger Group Inc. where he led its oil and gas investment efforts since October 2011. Prior to joining Harbinger Group Inc., Mr. Giesler served in various oil and gas principal investing, financial and other roles with Harbinger Capital Partners, AIG FP, Morgan Stanley and Bain & Company. In addition to serving as a Director of Glacier Oil & Gas Corp. and its predecessor companies, Mr. Giesler has also served on the boards of Compass Production Partners, LP and North American Energy Partners, Inc. Mr. Giesler received his Bachelor of Arts from the University of Virginia and his Juris Doctorate from Harvard Law School. He is also a CFA Charterholder.

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SANDRIDGE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - CONTINUED

(Unaudited)

Mr. Giesler’s initial term as a member of the Board will end at the annual meeting of stockholders to be held in 2021. Mr. Giesler’s appointment was not pursuant to any arrangements or understandings between Mr. Giesler and the Company or any other person. Mr. Giesler has no direct or indirect material interest in any transaction or series of similar transactions contemplated by Item 404(a) of Regulation S-K. As a non-independent Director, the Company will not compensate Mr. Giesler for his services rendered as a member of the Board. However, Mr. Giesler will enter into the Company’s standard form of Directors’ indemnification agreement with the Company, pursuant to which the Company agrees to indemnify its Directors to the fullest extent permitted by applicable law and to advance expenses in connection with proceedings as described in the indemnification agreement.

Royalty Trust Right of First Refusal

The Company is a party to the Amended and Restated Trust Agreement of SandRidge Mississippian Trust II (the “Trust”), dated April 23, 2012, by and among the Company, the Bank of New York Mellon Trust Company, N.A., and the Corporation Trust Company (the “Trust Agreement”). Pursuant to the Trust Agreement, the Company has a right of first refusal with respect to any sale of assets of the Trust to a third party following the occurrence of certain events (a “Triggering Event”). On February 14, 2020, the Trust began dissolving and winding up its activities, which is a Triggering Event. In April 2020, the Trust engaged a third-party advisor to assist with the marketing and sale of the Trust’s overriding royalty interests, which are in wells operated by the Company and subject to the right of first refusal. The Board and the Company evaluated the opportunity to acquire the properties related to the Trust’s overriding royalty interests and determined that it would be in the Company’s best interests to acquire such interests for a gross purchase price of $5.25 million (net purchase price of $3.28 million, given the Company's 37.6% ownership of the Trust).

On August 6, 2020 the Board authorized and the Company exercised its right of first refusal. The Company is currently negotiating this transaction.

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ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Introduction

The following discussion and analysis is intended to help the reader understand our business, financial condition, results of operations, liquidity and capital resources. This discussion and analysis should be read in conjunction with the accompanying unaudited condensed consolidated financial statements and the accompanying notes included in this Quarterly Report, as well as our audited consolidated financial statements and the accompanying notes included in the 2019 Form 10-K. Our discussion and analysis includes the following subjects:

•Overview;

•Consolidated Results of Operations;

•Liquidity and Capital Resources; and

•Critical Accounting Policies and Estimates

The financial information with respect to the three and six-month periods ended June 30, 2020, and 2019, discussed below, is unaudited. In the opinion of management, this information contains all adjustments, which consist only of normal recurring adjustments unless otherwise disclosed, necessary to state fairly the accompanying unaudited condensed consolidated financial statements. The results of operations for the interim periods are not necessarily indicative of the results of operations for the full fiscal year.

Overview

We are an oil and natural gas company with a principal focus on the acquisition, development and production of hydrocarbon resources in the United States.

Given current economic conditions, we have further reduced our capital expenditures budget for 2020 from $25.9 million to $4.6 million, which is exclusively comprised of capital workovers. We did not drill or complete any wells during the three and six-month period ended June 30, 2020, and do not expect to drill or complete any wells during 2020. During the three and six-month periods ended June 30, 2019, we drilled nine and 21 gross wells, respectively (6.6 and 13.5 net wells, respectively). Three and 11 of the gross wells drilled respectively in the three and six-month periods ended June 30, 2019 were located in the Mid-Continent. The remaining six and 10 gross wells drilled respectively in the three and six-month periods ended June 30, 2019 were located in the North Park Basin.

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The chart below shows production by product for the three and six-month periods ended June 30, 2020 and 2019:

Recent Events

•Effective July 29, 2020, the Board, upon recommendation of the Board's Nominating and Governance Committee, appointed Mr. Carl F. Giesler, Jr., the Company's President and Chief Executive Officer, to serve as a member of the Board. Mr. Giesler's initial term as a member of the Board will end at the annual meeting of stockholders to be held in 2021.

•In July 2020, the Board declared a dividend distribution of one right (a “Right”) for each outstanding share of Company common stock, par value $0.001 per share to stockholders of record at the close of business on July 13, 2020. Each Right entitles its holder, under certain circumstances, to purchase from the Company one one-thousandth of a share of Series A Junior Participating Preferred Stock of the Company, par value $0.001 per share, at an exercise price of $5.00 per Right, subject to adjustment. The description and terms of the Rights are set forth in the tax benefits preservation plan, dated as of July 1, 2020, between the Company and American Stock Transfer & Trust Company, LLC, as rights agent (and any successor rights agent, the “Rights Agent”).

•Effective July 1, 2020, the Board appointed Mr. Salah Gamoudi as the Company’s Chief Financial Officer and Chief Accounting Officer. Mr. Gamoudi, age 34, most recently served as the Company’s Vice President of Accounting and Finance beginning April 27, 2020. Prior to joining the Company, Mr. Gamoudi served as a Vice President and Chief Accounting Officer at Jones Energy, Inc. from October 2018 to April 2020. Jones Energy, Inc. filed for protection under Chapter 11 of the U.S. Bankruptcy Code on April 14, 2019. Immediately before serving as Vice President and Chief Accounting Officer at Jones Energy, Inc., Mr. Gamoudi served as Chief Accounting Officer and Controller of Remora Petroleum, L.P. from 2017 to 2018. From 2015 to 2017, he served as Corporate Controller of Glacier Oil & Gas and its predecessor entity. From 2013 to 2015, he served as SOX and Internal Audit Manager of LRR Energy, L.P. and Lime Rock Resources. Prior to that, he served as an auditor for Deloitte and for Ernst & Young LLP. Mr. Gamoudi has a Bachelor of Arts in Accounting from Portland State University and is a Certified Public Accountant.

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•In May 2020, we entered into an agreement for the sale of our corporate headquarters building located in Oklahoma City, OK. We expect the sale to be completed in the third quarter of 2020 for proceeds of approximately $35.5 million.

•Royalty Trust: SandRidge Mississippian Trust II: The Company is a party to the Amended and Restated Trust Agreement of SandRidge Mississippian Trust II (the “Trust”), dated April 23, 2012, by and among the Company, the Bank of New York Mellon Trust Company, N.A., and the Corporation Trust Company (the “Trust Agreement”). Pursuant to the Trust Agreement, the Company has a right of first refusal with respect to any sale of assets of the Trust to a third party following the occurrence of certain events (a “Triggering Event”). On February 14, 2020, the Trust began dissolving and winding up its activities, which is a Triggering Event. In April 2020, the Trust engaged a third-party advisor to assist with the marketing and sale of the Trust’s overriding royalty interests, which are in wells operated by the Company and subject to the right of first refusal. The Board and the Company evaluated the opportunity to acquire the properties related to the Trust’s overriding royalty interests and determined that it would be in the Company’s best interests to acquire such interests for a gross purchase price of $5.25 million (net purchase price of $3.28 million, given the Company's 37.6% ownership of the Trust). On August 6, 2020 the Board authorized and the Company exercised its right of first refusal. The Company is currently negotiating this transaction.

•On April 14, 2020, upon mutual agreement, we announced the planned departures of Michael A. Johnson from his position as Senior Vice President and Chief Financial Officer and John P. Suter from his position as Executive Vice President and Chief Operating Officer, effective July 1, 2020.

•On April 5, 2020, Bob G. Alexander, a member of the Board passed away. Mr. Alexander served on both the Audit Committee and Nominating Committee of the Board. Following Mr. Alexander’s passing, the Board appointed John. J. Lipinski to the Audit Committee and appointed Jonathan Christodoro to the Nominating and Governance Committee and appointed Mr. Lipinski as chairman of the committee.

•Effective April 6, 2020, the Board appointed Carl F. Giesler, Jr. as the Company’s President and Chief Executive Officer.

•In April 2020, additional personnel and non-personnel cost reductions were carried out and our capital expenditures guidance was revised in order to further reduce future costs as discussed in “Outlook” below.

•In April 2020, the borrowing base on our credit facility was reduced to $75.0 million from $225.0 million during the semi-annual redetermination. The credit facility has a maturity date of April 1, 2021 and amounts outstanding after April 1, 2020 are considered short-term borrowings under GAAP.

•In December 2019, COVID-19 was identified and subsequently declared a pandemic by the World Health Organization in March 2020. As a result, there has been a significant reduction in demand for and prices of crude oil, natural gas and NGL, and we had to close our headquarters and issue a work from home policy to protect our employees and others from potential virus transmission.

Outlook

The COVID-19 pandemic and other pricing volatility caused by the announcement of production increases by Saudi Arabia-led OPEC and Russia caused a steep decline in oil prices in March 2020, which further decreased to historic lows in April 2020. Although we cannot reasonably estimate what the full impact of the COVID-19 pandemic and other market volatility will have on our business, we expect it will have a material, adverse impact on near-term future revenues and overall profitability. As a result, we have withdrawn our guidance from February 2020 and reduced our 2020 capital expenditures budget from $25.9 million to $4.6 million. Additionally, we have implemented several additional initiatives to maximize free cash flow, reduce our debt level, maximize our liquidity position and, ultimately realize greater shareholder value. These initiatives included personnel and non-personnel cost reductions, the sale of the company headquarters, and entering into additional commodity derivative contracts for natural gas during the remainder of calendar year 2020 and in year 2021.

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Consolidated Results of Operations

The majority of our consolidated revenues and cash flow are generated from the production and sale of oil, natural gas and NGLs. Our revenues, profitability and future growth depend substantially on prices received for our production, the quantity of oil, natural gas and NGLs we produce, our ability to find and economically develop and produce our reserves, and changes in the fair value of our commodity derivative contracts. Prices for oil, natural gas and NGLs fluctuate widely and are difficult to predict.

To provide information on the general trend in pricing, the average NYMEX prices for oil and natural gas during the three and six-month periods ended June 30, 2020, and 2019 are shown in the table below:

        

						Three Months Ended June 30,																		Six Months Ended June 30,
						2020						2019						2020						2019
NYMEX Oil (per Bbl)						$	28.00					$	59.91					$	36.83					$	57.45
NYMEX Natural gas (per MMBtu)						$	1.75					$	2.51					$	1.81					$	2.69

To reduce our exposure to price fluctuations, from time to time we enter into commodity derivative contracts for a portion of our anticipated future oil and natural gas production depending on the Company's view of opportunities under then-prevailing market conditions as discussed in “Item 3. Quantitative and Qualitative Disclosures About Market Risk.” Reducing our exposure to price volatility helps mitigate the risk that we will not have adequate funds available for our capital expenditure and other programs. During periods where the strike prices for our commodity derivative contracts are below market prices at the time of settlement, we may not fully benefit from increases in the market price of oil and natural gas. Conversely, during periods of declining oil and natural gas market prices, our commodity derivative contracts may partially offset declining revenues and cash flow to the extent strike prices for our contracts are above market prices at the time of settlement.

Revenues

Consolidated revenues for the three and six-month periods ended June 30, 2020, and 2019 are presented in the table below (in thousands):

			Three Months Ended June 30,																		Six Months Ended June 30,
			2020						2019						2020						2019
Oil			$	11,554					$	55,615					$	40,208					$	98,774
NGL			1,591						9,413						7,525						22,524
Natural gas			3,303						10,168						8,854						26,946
Other			207						192						397						380
Total revenues			$	16,655					$	75,388					$	56,984					$	148,624

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Oil, Natural Gas and NGL Production and Pricing

The Company's production and pricing information for the three and six-month periods ended June 30, 2020, and 2019 is shown in the table below:

			Three Months Ended June 30,																								Six Months Ended June 30,
			2020						2019												2020						2019
Production data
Oil (MBbls)			520						984												1,202						1,833
NGL (MBbls)			681						830												1,451						1,706
Natural gas (MMcf)			5,697						8,476												12,391						17,096
Total volumes (MBoe)			2,151						3,227												4,718						6,388
Average daily total volumes (MBoe/d)			23.6						35.5												25.9						35.3
Average prices—as reported(1)
Oil (per Bbl)			$	22.22					$	56.52											$	33.45					$	53.89
NGL (per Bbl)			$	2.34					$	11.34											$	5.19					$	13.20
Natural gas (per Mcf)			$	0.58					$	1.20											$	0.71					$	1.58
Total (per Boe)			$	7.65					$	23.30											$	11.99					$	23.21
Average prices—including impact of derivative contract settlements
Oil (per Bbl)			$	33.47					$	56.52											$	41.72					$	53.89
NGL (per Bbl)			$	2.34					$	11.34											$	5.19					$	13.20
Natural gas (per Mcf)			$	0.69					$	1.20											$	0.77					$	1.87
Total (per Boe)			$	10.67					$	23.30											$	14.24					$	24.00

__________________

1.Prices represent actual average sales prices for the periods presented and do not include effects of derivatives.

The table below presents production by area of operation for the three and six-month periods ended June 30, 2020, and 2019:

			Three Months Ended June 30,																																										Six Months Ended June 30,
			2020																		2019																		2020																		2019
			Production (MBoe)						% of Total						Production (MBoe)						% of Total						Production (MBoe)						% of Total						Production (MBoe)						% of Total
Mississippian Lime			1,786						83.0		%				2,468						76.5		%				3,847						81.5		%				5,118						80.2		%
NW STACK			143						6.6		%				309						9.6		%				321						6.8		%				545						8.5		%
North Park Basin			222						10.3		%				450						13.9		%				550						11.7		%				725						11.3		%
Total			2,151						100.0		%				3,227						100.0		%				4,718						100.0		%				6,388						100.0		%

Variances in oil, natural gas and NGL revenues attributable to changes in the average prices received for our production and total production volumes sold for the three and six-month periods ended June 30, 2020, and 2019 are shown in the table below (in thousands):

			Three Months Ended June 30, 2020						Six Months Ended June 30, 2020
2019 oil, natural gas and NGL revenues			$	75,196					$	148,244
Change due to production volumes			$	(12,274)					$	(20,028)
Change due to average prices			$	(46,474)					$	(71,629)
2020 oil, natural gas and NGL revenues			$	16,448					$	56,587

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Revenues from oil, natural gas and NGL sales decreased $58.7 million, or 77.9% for the quarter ended June 30, 2020 as compared to the quarter ended June 30, 2019. Revenues from oil, natural gas and NGL sales decreased $91.6 million or 61.7% for the six months ended June 30, 2020 as compared to the six months ended June 30, 2019. The average prices for oil, natural gas and NGL's declined significantly during both periods, due largely to an increase in anticipated global supplies of these commodities after a pledged increase in oil production from Saudi Arabia-led OPEC, and the reduction in demand stemming from the COVID-19 pandemic. See “Item 1A. Risk Factors” included in Part II of this Quarterly Report for additional discussion of the potential impact these events may have on our future revenues.

The decline in production between the three months ended June 30, 2020 and 2019, as well as the six months ended June 30, 2020 and 2019 largely resulted from the absence of newly drilled wells in 2020 and natural production declines in our existing producing wells in the Mississippian Lime, and to a lesser extent, the NW STACK and North Park Basin.

Operating Expenses

Operating expenses for the three and six-month periods ended June 30, 2020, and 2019 consisted of the following (in thousands): 

			Three Months Ended June 30,																		Six Months Ended June 30,
			2020						2019						2020						2019
Lease operating expenses			$	8,698					$	25,076					$	24,340					$	47,855
Production, ad valorem, and other taxes			1,854						5,877						5,053						10,957
Depreciation and depletion—oil and natural gas			13,348						39,419						38,203						75,884
Depreciation and amortization—other			1,739						2,986						4,373						5,929
Total operating expenses			$	25,639					$	73,358					$	71,969					$	140,625
Lease operating expenses ($/Boe)			$	4.04					$	7.77					$	5.16					$	7.49
Production, ad valorem, and other taxes ($/Boe)			$	0.86					$	1.82					$	1.07					$	1.72
Depreciation and depletion—oil and natural gas ($/Boe)			$	6.21					$	12.22					$	8.10					$	11.88
Production, ad valorem, and other taxes (% of oil, natural gas, and NGL revenue)			11.3		%				7.8		%				8.9		%				7.4		%

Lease operating expenses decreased by $16.4 million or $3.73/Boe for the three months ended June 30, 2020, as compared to the three months ended June 30, 2019. Lease operating expenses decreased by $23.5 million or $2.33/Boe for the six months ended June 30, 2020, as compared to the six months ended June 30, 2019. These decreases primarily resulted from field personnel reductions in force, in addition to the shut-in of wells that had become uneconomic due to natural production declines and deteriorating pricing in the three and six-month periods ended June 30, 2020.

Production, ad valorem, and other taxes have continued to decrease primarily due to declining production and revenues as discussed above. Further, they have increased as a percentage of oil, natural gas, and NGL revenue for the three and six months ended June 30, 2020 as compared to comparable periods in 2019, primarily due to ad valorem taxes remaining consistent throughout 2020 while revenues have declined during 2020.

The average depreciation and depletion rate for our oil and natural gas properties for the three months ended June 30, 2020 decreased by $6.01/Boe from the three months ended June 30, 2019. The average depreciation and depletion rate for our oil and natural gas properties for the six months ended June 30, 2020 decreased by $3.78/Boe from the six months ended June 30, 2019. These decreases were primarily due to the full cost ceiling test impairments recorded in the third and fourth quarters of 2019, as well as the first quarter of 2020.

Impairment

In the three-month period ended June 30, 2020, we recorded a total impairment charge of $201.8 million, which included a full cost ceiling limitation impairment charge of $163.8 million, and an impairment charge of $38.0 million to write down the value of the Company's office headquarters, classified as assets held for sale, to its estimated fair value less estimated costs to sell the building.

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In the six-month period ended June 30, 2020, we recorded a total impairment charge of $209.8 million, which included a full cost ceiling limitation impairment charge of $171.8 million, and an impairment charge of $38.0 million to write down the value of the Company's office headquarters, classified as assets held for sale, to its estimated fair value less estimated costs to sell the building.

The ceiling limitation impairment charges recorded in the three and six-month period ended June 30, 2020 resulted from various factors including a decrease in the trailing twelve-month weighted average natural gas price in 2020. No impairment charges were recorded in the three and six month period ended June 30, 2019.

Calculation of the full cost ceiling test is based on, among other factors, average prices for the trailing twelve-month period determined by reference to the first-day-of-the-month index prices (“SEC prices”) as adjusted for price differentials and other contractual arrangements. The SEC prices utilized in the calculation of proved reserves included in the full cost ceiling test at June 30, 2020 were $47.17 per barrel of oil and $2.07 per Mcf of natural gas, before price differential adjustments.

Based on the SEC prices over the eleven months ended July 7, 2020, as well as the short-term pricing outlook for the remainder of the third quarter 2020, we anticipate the SEC prices utilized in the June 30, 2020 full cost ceiling test may be $43.27 per barrel of oil and $1.96 per Mcf of natural gas, (the "estimated third quarter prices"). Applying these estimated third quarter prices, and holding all other inputs constant to those used in the calculation of our June 30, 2020 ceiling test, we expect to incur an additional impairment charge of approximately $31.9 million in the third quarter of 2020.

Any actual full cost ceiling limitation impairment recognized in future quarters may fluctuate significantly from projected amounts based on the outcome of numerous other factors such as additional declines in the actual trailing twelve-month SEC prices, changes in estimated future development costs and operating expenses, and other adjustments to our levels of proved reserves. Any such ceiling test impairments in 2020 could be material to our net earnings.

Full cost pool impairments have no impact to our cash flow or liquidity.

Other Operating Expenses

Other operating expenses for the three and six-month periods ended June 30, 2020, and 2019 consisted of the following (in thousands):

			Three Months Ended June 30,																		Six Months Ended June 30,
			2020						2019						2020						2019
General and administrative			$	4,314					$	10,084					$	9,797					$	20,023
Restructuring expenses			444						—						444						—
Employee termination benefits			1,993						4,465						5,247						4,465
(Gain) loss on derivative contracts			(2,241)						—						(12,467)						209
Other operating expense			108						37						385						119
Total other operating expenses			$	4,618					$	14,586					$	3,406					$	24,816

General and administrative expenses decreased by $5.8 million for the three months ended June 30, 2020, compared to the same period in 2019. General and administrative expenses decreased by $10.2 million for the six months ended June 30, 2020, compared to the same period in 2019. These decreases resulted primarily from a reduction in compensation related costs after completing reductions in force during the second quarter of 2019 and the first half of 2020. Part of the decrease is also due to reductions in professional costs such as legal expenses, audit fees and consulting services.

Restructuring expenses represent fees and costs associated with our outsourcing and relocation of certain corporate specific functions that are of a non-recurring nature.

Employee termination benefits for the three and six-month periods ended June 30, 2020 and 2019 include cash and share-based severance costs incurred for the reduction in force in the relevant periods. See “Note 12 - Employee Termination Benefits” in the accompanying unaudited condensed consolidated financial statements for additional discussion of these expenses.

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The following table summarizes derivative activity for the three and six-month periods ended June 30, 2020, and 2019 (in thousands):

			Three Months Ended June 30,																		Six Months Ended June 30,
			2020						2019						2020						2019
Gain (loss) on commodity derivative contracts			$	2,241					$	—					$	12,467					$	(209)
Cash received on settlements			$	6,490					$	—					$	10,577					$	5,078

Our derivative contracts are not designated as accounting hedges and, as a result, changes in their fair values are recorded each quarter as a component of operating expenses. Internally, management views the settlement of commodity derivative contracts at contractual maturity as adjustments to the price received for oil and natural gas production to determine “effective prices.” In general, cash is received on settlement of contracts due to lower oil and natural gas prices at the time of settlement compared to the contract price for our commodity derivative contracts, and cash is paid on settlement of contracts due to higher oil and natural gas prices at the time of settlement compared to the contract price for our commodity derivative contracts. In April 2020, we entered into additional natural gas commodity derivative contracts as discussed in “Item 3. Quantitative and Qualitative Disclosures about Market Risk” included in Part I of this Quarterly Report.

Other Income (Expense)

The Company’s other income (expense) for the three and six-month periods ended June 30, 2020, and 2019 are presented in the table below (in thousands):

			Three Months Ended June 30,																		Six Months Ended June 30,
			2020						2019						2020						2019
Other income (expense)
Interest expense, net			$	(447)					$	(702)					$	(1,084)					$	(1,287)
Other income (expense), net			58						(26)						134						(457)
Total other expense			$	(389)					$	(728)					$	(950)					$	(1,744)

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Liquidity and Capital Resources

As of June 30, 2020, we had cash and cash equivalents, excluding restricted cash, of $13.5 million. Additionally, we had $59.0 million outstanding under our $75.0 million credit facility which matures on April 1, 2021, and $4.3 million in outstanding letters of credit, which reduce the amount available under the credit facility on a dollar-for dollar basis. This leaves an additional $11.7 million available to be borrowed under the credit facility.

As discussed in “— Recent Events” and “— Outlook” above, we have undertaken several initiatives in the second quarter of 2020 which we believe have the potential to positively impact our ability to repay our outstanding credit facility borrowings at or before maturity. These initiatives are also expected to maximize free cash flow, maximize our liquidity position and, ultimately realize greater shareholder value to address the negative impact of the COVID-19 pandemic and commodity price volatility on our financial position and future liquidity. These initiatives included personnel and non-personnel cost reductions, the sale of our corporate headquarters, and entering into commodity derivative contracts for natural gas to reduce our exposure to near term commodity price volatility. We are actively working to refinance the outstanding borrowings under our credit facility.

As of July 31, 2020, we had approximately $16.3 million in cash and cash equivalents, excluding restricted cash, $59.0 million outstanding under our credit facility, and $4.3 million in outstanding letters of credit. Amounts outstanding under the credit facility after April 1, 2020 are classified as short-term borrowings under GAAP. We currently project that we will not have sufficient cash on hand or available liquidity to repay the outstanding credit facility balance at maturity without the company taking specific actions to alleviate this liquidity short-fall. These conditions and events raise substantial doubt about our ability to continue as a going concern. Our failure to close on the corporate building sale and use the proceeds to repay the outstanding borrowings at maturity or otherwise restate or amend our current credit facility terms prior to maturity could result in the potential foreclosure on the collateral securing the credit facility.

We are unable to project the full impact the COVID-19 pandemic will have on our financial position and results of operations at this time, but these measures, along with amounts available to be drawn on our credit facility, cash on hand, and other cash flows from operations are expected to provide ample liquidity for the next 12 months. While we cannot give absolute assurance that our plans will succeed, we have concluded that our plans are probable of being achieved to alleviate substantial doubt about the Company’s ability to continue as a going concern.

Working Capital and Sources and Uses of Cash

Our principal sources of liquidity for the next year include cash flows from operations, cash on hand and amounts available under our credit facility. As discussed in “— Outlook” above to the accompanying unaudited condensed consolidated financial statements and “Item 1A. Risk Factors” included in Part II of this Quarterly Report, we expect the COVID-19 pandemic and other market volatility factors including production decisions made by OPEC and its affiliate countries to have a material, adverse impact on future revenue growth and overall profitability for the foreseeable future.

We had a working capital deficit of $53.3 million at June 30, 2020, as compared to a deficit of $49.8 million at December 31, 2019. The change was largely due to the negative impact on working capital resulting from the reclassification of our credit facility from long-term debt to current maturities of long-term debt, partially offset by the positive impact resulting from the reclassification of our office headquarters from other property, plant and equipment, net, to assets held for sale. Further, working capital was negatively impacted by a decrease in accounts receivable for oil and gas sales as revenues continue to decline, and was positively impacted by an increase in our short-term derivatives assets at June 30, 2020 resulting from a decrease in the market price for natural gas compared to contract prices for our open natural gas derivatives at June 30, 2020. Management is pursuing an agreement to refinance the outstanding borrowings under the credit facility.

Cash Flows

Our cash flows from operations, which impact our ability to fund our capital expenditures, are substantially dependent on current and future prices for oil and natural gas, which historically have been, and may continue to be, volatile. Cash flows from operations are also affected by timing of cash receipts and disbursements and changes in other working capital assets and liabilities.

Our cash flows for the six-month periods ended June 30, 2020, and 2019 are presented in the following table and discussed below (in thousands):

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			Six Months Ended June 30,
			2020						2019
Cash flows provided by operating activities			$	13,462					$	62,473
Cash flows used in investing activities			(5,308)						(122,588)
Cash flows provided by financing activities			805						50,259
Net increase (decrease) in cash and cash equivalents			$	8,959					$	(9,856)

Cash Flows from Operating Activities

The $49.0 million decrease in cash flows from operating activities for the six-month period ended June 30, 2020 compared to the same period in 2019, is primarily due to the significant decline in revenues, which was partially offset by reductions in general and administrative costs and lease operating expenses as well as the other changes in working capital discussed previously.

Cash Flows from Investing Activities

Our cash flows used in investing activities during the six-month period ended June 30, 2020 primarily reflects cash payments made for capital expenditures accrued at December 31, 2019 as shown in the table below. As previously discussed, we have significantly reduced our 2020 capital expenditures program due to current commodity price and demand volatility.

During the six-month period ended June 30, 2019, cash flows used in investing activities primarily consisted of capital expenditures for drilling and completion activities.

Capital expenditures for the six-month periods ended June 30, 2020, and 2019 are summarized below (in thousands):

			Six Months Ended June 30,
			2020						2019
Capital Expenditures
Drilling, completion and capital workovers			$	2,430					$	103,693
Leasehold and geophysical			497						2,811
Other - corporate			—						162
Capital expenditures, excluding acquisitions (on an accrual basis)			2,927						106,666
Acquisitions			—						(236)
Capital expenditures, including acquisitions			2,927						106,430
Change in capital accruals(1)			3,887						17,010
Total cash paid for capital expenditures			$	6,814					$	123,440

__________________

1.Reflects cash paid or adjustments to accruals during the period presented for expenditures related to prior period capital expenditures.

Cash Flows from Financing Activities

Cash provided by financing activities for the six-month period ended June 30, 2020 consisted primarily of net borrowings under the credit facility.

Indebtedness

See “— Recent Events,” “Note 7 - Debt” to the accompanying unaudited condensed consolidated financial statements for additional discussion of our credit facility's terms and covenant restrictions.

Contractual Obligations and Off-Balance Sheet Arrangements

At June 30, 2020, our contractual obligations included asset retirement obligations, long-term debt obligations and leases and other individually insignificant obligations. Additionally, we have certain financial instruments representing potential

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commitments that were incurred in the normal course of business to support our operations, including standby letters of credit and surety bonds. The underlying liabilities insured by these instruments are reflected in our balance sheets, where applicable. Therefore, no additional liability is reflected for the letters of credit and surety bonds.

Our long-term debt outstanding increased by $1.5 million at June 30, 2020 compared to December 31, 2019, due to additional borrowings, offset by repayments of a portion of the borrowings previously drawn on the Company's credit facility, which matures in April 2021. There were no other significant changes in total contractual obligations and off-balance sheet arrangements from those reported in the 2019 Form 10-K.

Critical Accounting Policies and Estimates

For a description of our critical accounting policies and estimates, refer to Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations included in the 2019 Form 10-K. For a discussion of recent accounting pronouncements, newly adopted and recent accounting pronouncements not yet adopted, see “Note 1 - Basis of Presentation” to the accompanying unaudited condensed consolidated financial statements included in Item 1 of this Quarterly Report. We did not have any material changes in critical accounting policies, estimates, judgments and assumptions during the first six months of 2020.

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ITEM 3. Quantitative and Qualitative Disclosures About Market Risk

General

This discussion provides information about the financial instruments we use to manage commodity prices. All contracts are settled in cash and do not require the actual delivery of a commodity at settlement. Additionally, our exposure to credit risk and interest rate risk is also discussed.

Commodity Price Risk. Our most significant market risk relates to the prices we receive for our oil, natural gas and NGLs. Due to the historical price volatility of these commodities, from time to time, depending upon our view of opportunities under the then-prevailing current market conditions, we enter into commodity price derivative contracts for a portion of our anticipated production volumes for the purpose of reducing variability of oil and natural gas prices we receive. Our credit facility limits our ability to enter into derivative transactions to 90% of expected production volumes from estimated proved reserves over the period covered by the transactions.

Historically, we have used a variety of commodity-based derivative contracts, including fixed price swaps, basis swaps and collars. At June 30, 2020, the Company's open derivative contracts consisted of natural gas commodity derivative contracts under which we will receive a fixed price for the contract and pay a floating market price to the counterparty over a specified period for a contracted volume. These commodity derivative contracts consisted of the following:

						Notional (MMBtu)						Weighted Average Fixed Price per Unit
Natural Gas Price Swaps: July 2020 - October 2020						4,920,000						$	2.14

Further, subsequent to June 30, 2020, in July 2020, the Company entered into derivative contracts consisting of natural gas commodity derivative contracts under which we will receive a fixed price for the contract and pay a floating market price to the counterparty over a specified period for a contracted volume. These commodity derivative contracts consisted of the following:

			Notional (MMBtu)						Weighted Average Fixed Price per Unit
Natural Gas Price Swaps: November 2020 - December 2020			2,135,000						$	2.54
Natural Gas Price Swaps: January 2021 - December 2021			10,950,000						$	2.61

Because we have not designated any of our derivative contracts as hedges for accounting purposes, changes in the fair value of our derivative contracts are recognized as gains and losses in current period earnings. As a result, our current period earnings may be significantly affected by changes in the fair value of our commodity derivative contracts. Changes in fair value are principally measured based on a comparison of future prices to the contract price at the period-end.

The following table summarizes derivative activity for the three and six-month periods ended June 30, 2020, and 2019 (in thousands):

			Three Months Ended June 30,																		Six Months Ended June 30,
			2020						2019						2020						2019
Gain (loss) on commodity derivative contracts			$	2,241					$	—					$	12,467					$	(209)
Cash received on settlements			$	6,490					$	—					$	10,577					$	5,078

See “Note 3 - Derivatives” to the accompanying unaudited condensed consolidated financial statements included in this Quarterly Report for additional information regarding our commodity derivatives.

Credit Risk. We are exposed to credit risk related to counterparties to our derivative financial contracts. All of our derivative transactions have been carried out in the over-the-counter market. The use of derivative transactions in over-the-counter markets involves the risk that the counterparties may be unable to meet the financial terms of the transactions. The counterparties for all of our derivative transactions have had an “investment grade” credit rating. We monitor the credit ratings of our derivative counterparties and consider our counterparties’ credit default risk ratings in determining the fair value of our

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derivative contracts. Our derivative contracts are with multiple counterparties to minimize exposure to any individual counterparty.

We do not require collateral or other security from counterparties to support derivative instruments. We have master netting agreements with each of our derivative contract counterparties, which allow us to net our derivative assets and liabilities by commodity type with the same counterparty. This limits our maximum amount of loss under derivative transactions due to our ability to net the amounts due from the counterparties under any outstanding commodity derivative contracts. Our loss is further limited as any amounts due from a defaulting counterparty that is also a lender under the credit facility can be offset against amounts owed, if any, to such counterparty. As of June 30, 2020, the counterparties to our open commodity derivative contracts consisted of two financial institutions, both of which are also lenders under our credit facility. As a result, we are not required to post additional collateral under our commodity derivative contracts.

We are also exposed to credit risk related to the collection of receivables from our joint interest partners for their proportionate share of expenditures made on projects we operate. As discussed in “Note 1 - Basis of Presentation” to the accompanying unaudited consolidated financial statements, we adopted ASU 2016-13 on January 1, 2020, and recorded an immaterial adjustment to our joint interest receivables for estimated credit losses on our joint interest receivables.

Interest Rate Risk. We are exposed to interest rate risk on our credit facility. This variable interest rate on our credit facility fluctuates and exposes us to short-term changes in market interest rates as our interest obligation on this instrument is based on prevailing market interest rates, primarily LIBOR and the federal funds rate. We had $59.0 million in outstanding variable rate debt as of June 30, 2020.

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ITEM 4. Controls and Procedures

Disclosure Controls and Procedures

Under the supervision and with the participation of the Company’s management, including the Company’s CEO and CFO, the Company performed an evaluation of the effectiveness of the design and operation of its disclosure controls and procedures pursuant to Exchange Act Rules 13a-15 and 15d-15 as of the end of the period covered by this Quarterly Report. Based on that evaluation, the Company’s CEO and CFO concluded that the Company’s disclosure controls and procedures were effective as of June 30, 2020, to provide reasonable assurance that the information required to be disclosed by the Company in its reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Securities and Exchange Commission, and such information is accumulated and communicated to management, as appropriate to allow timely decisions regarding required disclosure.

Changes in Internal Control Over Financial Reporting

There was no change in the Company’s internal control over financial reporting during the quarter ended June 30, 2020 that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.

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PART II. Other Information

ITEM 1. Legal Proceedings

As previously disclosed, on May 16, 2016, the Debtors filed voluntary petitions for reorganization under Chapter 11 of the United States Bankruptcy Code in the Bankruptcy Court. The Bankruptcy Court confirmed the Plan on September 9, 2016, and the Debtors subsequently emerged from bankruptcy on October 4, 2016.

Pursuant to the Plan, claims against the Company were discharged without recovery in each of the following consolidated Cases:

•In re SandRidge Energy, Inc. Securities Litigation, Case No. 5:12-cv-01341-LRW, USDC, Western District of Oklahoma; and

•Ivan Nibur, Lawrence Ross, Jase Luna, Matthew Willenbucher, and the Duane & Virginia Lanier Trust v. SandRidge Mississippian Trust I, et al., Case No. 5:15-cv-00634-SLP, USDC, Western District of Oklahoma

The lead plaintiffs in both In re SandRidge Energy, Inc. Securities Litigation and Lanier Trust assert claims on behalf of themselves and (i) in In re SandRidge Energy, Inc. Securities Litigation, a class of all purchasers of SandRidge common stock from February 24, 2011 and November 8, 2012 under Sections 10(b) and 20(a) of the Securities Exchange Act of 1934, and Rule 10b-5 promulgated thereunder, and (ii) in Lanier Trust, a putative class of purchasers of SandRidge Mississippian Trust I and SandRidge Mississippian Trust II common units between April 7, 2011 and November 8, 2012 under Sections 11, 12(a)(2), and 15 of the Securities Act of 1933 and Sections 10(b) and 20(a) of the Securities Exchange Act of 1934, and Rule 10b-5 promulgated thereunder, both based on allegations that defendants, which include certain former officers of the Company and the SandRidge Mississippian Trust I, made misrepresentations or omissions concerning various topics including the performance of wells operated by the Company in the Mississippian region.

Discovery in each of the Cases closed on June 19, 2019. Following a hearing on class certification in each of the Cases on September 6, 2019, the court granted class certification in In re SandRidge Energy, Inc. Securities Litigation on September 30, 2019. The motion for class certification in Lanier Trust remains pending. On April 2, 2020, the individual defendants and SandRidge Mississippian Trust I filed motions for summary judgment seeking the dismissal of all claims asserted against them in the Lanier Trust matter. On the same date, the individual defendants filed motions for summary judgment seeking the dismissal of all claims asserted against them In re SandRidge Energy, Inc. Securities Litigation. The motions remain pending.

In each of the Cases, lead plaintiffs seek to recover unspecified damages, interest, costs and expenses incurred in the litigation on behalf of themselves and class members. Although the claims against the Company in each Case have been discharged pursuant to the Plan, the Company remains a nominal defendant in each of the Cases to the extent necessary to allow recovery from applicable insurance policies or proceeds. In addition, the Company owes indemnity obligations and/or the obligation to advance legal fees, to certain former officers who remain as defendants in each action. The Company may also be contractually obligated to indemnify the SandRidge Mississippian Trust I against losses, claims, damages, liabilities and expenses, including reasonable costs of investigation and attorney’s fees and expenses, arising out of the Cases, and such indemnification is not covered by insurance.

In light of the status of the Cases, and the facts, circumstances and legal theories relating thereto, the Company is not able to determine the likelihood of an outcome in either case or provide an estimate of any reasonably possible loss or range of possible loss related thereto. However, considering the erosion of insurance coverage available to the Company, such losses, if incurred, could be material. The Company has not established any liabilities relating to the Cases and believes that the plaintiffs’ claims are without merit. The Company intends to continue to vigorously defend against the Cases in its capacity as a nominal defendant.

In addition to the matters described above, the Company is involved in various lawsuits, claims and proceedings which are being handled and defended by the Company in the ordinary course of business.

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ITEM 1A. Risk Factors

Other than the risk factors below, there have been no material changes to the risk factors previously discussed in Item 1A—Risk Factors in the Company's 2019 Form 10-K.

The COVID-19 pandemic has adversely affected our business, and the ultimate effect on our operations and financial condition will depend on future developments, which are highly uncertain and cannot be predicted.

The COVID-19 pandemic has adversely affected the global economy, disrupted global supply chains and created significant volatility in the financial markets. In addition, the pandemic has resulted in travel restrictions, business closures and the institution of quarantining and other restrictions on movement in many communities. As a result, there has been a significant reduction in demand for and prices of crude oil, natural gas and NGL. If the reduced demand for and prices of crude oil, natural gas and NGL continue for a prolonged period, our operations, financial condition, cash flows, level of expenditures and the quantity of estimated proved reserves that may be attributed to our properties may be materially and adversely affected. Our operations also may be adversely affected if significant portions of our workforce are unable to work effectively, including because of illness, quarantines, government actions, or other restrictions in connection with the pandemic. We have already implemented workplace restrictions, including guidance for our employees to work remotely if able, in our offices and work sites for health and safety reasons and are continuing to monitor national, state and local government directives where we have operations and/or offices. Further, our business plan, including our financing and liquidity plan, includes, among other things, planned divestitures. If general economic conditions or conditions in the energy industry continue to deteriorate or remain uncertain for an extended period of time, we may not be able to complete these transactions on favorable terms, in a timely manner or at all. The extent to which the COVID-19 pandemic adversely affects our business, results of operations, and financial condition will depend on future developments, which are highly uncertain and cannot be predicted, including the scope and duration of the pandemic and actions taken by governmental authorities and other third parties in response to the pandemic.

Crude oil prices declined significantly in the first and second quarters of 2020 and, if oil prices continue to decline or remain at current levels for a prolonged period, our operations and financial condition may be materially and adversely affected.

In the first and second quarters of 2020, crude oil prices fell sharply and dramatically, due in part to significantly decreased demand as a result of the COVID-19 pandemic and the announcement by Saudi Arabia of a significant increase in its maximum crude oil production capacity as well as the announcement by Russia that previously agreed upon oil production cuts between members of the Organization of the Petroleum Exporting Countries and its broader partners (“OPEC+”) would expire on April 1, 2020, and the ensuing expiration thereof. On April 12, 2020, members of OPEC+ agreed to certain production cuts; however, these cuts are not expected to be enough to offset near-term demand loss attributable to the COVID-19 pandemic. If crude oil prices continue to decline or remain at current levels for a prolonged period, our operations, financial condition, cash flows, level of expenditures and the quantity of estimated proved reserves that may be attributed to our properties may be materially and adversely affected.

ITEM 2. Unregistered Sales of Equity Securities and Use of Proceeds

The following table presents a summary of share repurchases made by the Company during the three-month period ended June 30, 2020.

Period			Total Number of Shares Purchased(1)						Average Price Paid per Share						Total Number of Shares Purchased as Part of Publicly Announced Program						Maximum Approximate Dollar Value of Shares that May Yet Be Purchased Under the Program (in Millions)
April 1, 2020 - April 30, 2020			1,093						$	1.08					N/A						N/A
May 1, 2020 - May 31, 2020			—						$	—					N/A						N/A
June 1, 2020 - June 30, 2020			—						$	—					N/A						N/A
Total			1,093												—

___________________

(1) Includes shares of common stock tendered by employees in order to satisfy tax withholding requirements upon vesting of their stock awards. Shares withheld are initially recorded as treasury shares, then immediately retired.

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ITEM 3. Defaults upon Senior Securities

None.

ITEM 4. Mine Safety Disclosures

None.

ITEM 5. Other Information

None.

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ITEM 6. Exhibits

Incorporated by Reference

Exhibit No.

Exhibit Description

Form

SEC File No.

Exhibit

Filing Date

Filed Herewith

2.1

Amended Joint Chapter 11 Plan of Reorganization of SandRidge Energy, Inc., et al., dated September 19, 2016

8-A

001-33784

2.1

10/4/2016

3.1

Amended and Restated Certificate of Incorporation of SandRidge Energy, Inc.

8-A

001-33784

3.1

10/4/2016

3.2

Amended and Restated Bylaws of SandRidge Energy, Inc.

8-A

001-33784

3.2

10/4/2016

4.1

Certificate of Designation of Series A Junior Participating Preferred Stock of Sandridge Energy, Inc. and American Stock Transfer & Trust Company, LLC

8-A

001-33784

3.1

7/2/2020

10.1

Offer Letter, dated April 6, 2020, by and between the Company and Carl F. Giesler, Jr.

8-K

001-33784

10.1

4/7/2020

10.2

Letter Agreement, dated February 21, 2020, by and between the Company and John Suter

10-K

001-33784

10.11

2/27/2020

10.3

Offer Letter, dated April 24, 2020, by and between the Company and Salah Gamoudi

8-K

001-33784

10.1

7/2/2020

10.4

Real Estate Purchase and Sale Agreement, dated May 15, 2020, by and between Robinson Park, LLC and SandRidge Realty LLC

8-K

001-33784

10.1

5/19/2020

10.5

Tax Benefits Preservation Plan, dated July 1, 2020, between SandRidge Energy, Inc. and American Stock Transfer & Trust Company, LLC

8-K

001-33784

4.1

7/2/2020

31.1

Section 302 Certification—Chief Executive Officer

*

31.2

Section 302 Certification—Chief Financial Officer

*

32.1

Section 906 Certifications of Chief Executive Officer and Chief Financial Officer

*

101.INS

XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

*

101.SCH

XBRL Taxonomy Extension Schema Document

*

101.CAL

XBRL Taxonomy Extension Calculation Linkbase Document

*

101.DEF

XBRL Taxonomy Extension Definition Document

*

101.LAB

XBRL Taxonomy Extension Label Linkbase Document

*

101.PRE

XBRL Taxonomy Extension Presentation Linkbase Document

*

104

Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

*

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SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

			SandRidge Energy, Inc.
Date: August 6, 2020			By:			/s/    Salah Gamoudi
						Salah Gamoudi Chief Financial Officer and Chief Accounting Officer

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