Chord Energy (CHRD) 10-Q 2021 Q3 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

 

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

For the quarterly period ended September 30, 2021

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: 1-34776

Oasis Petroleum Inc.

(Exact name of registrant as specified in its charter)

 

Delaware	80-0554627
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
1001 Fannin Street, Suite 1500
Houston, Texas	77002
(Address of principal executive offices)	(Zip Code)

(281) 404-9500

(Registrant’s telephone number, including area code)

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

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock	OAS	The Nasdaq Stock Market LLC

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  ☒   No ☐

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 (§232.405 of this chapter) 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.  ☐ 

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

Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Section 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  ý   No  ¨

Number of shares of the registrant’s common stock outstanding at November 2, 2021: 19,749,642 shares.

OASIS PETROLEUM INC.

FORM 10-Q

FOR THE QUARTER ENDED SEPTEMBER 30, 2021

TABLE OF CONTENTS

	Page
PART I — FINANCIAL INFORMATION	1
Item 1. — Financial Statements (Unaudited)	1
Condensed Consolidated Balance Sheets at September 30, 2021 and December 31, 2020	1
Condensed Consolidated Statements of Operations for the Three and Nine Months Ended September 30, 2021 (Successor) and 2020 (Predecessor)	3
Condensed Consolidated Statements of Changes in Stockholders’ Equity (Deficit)	5
Condensed Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2021 (Successor) and 2020 (Predecessor)	7
Notes to Condensed Consolidated Financial Statements	9
1. Organization and Operations of the Company	9
2. Summary of Significant Accounting Policies	9
3. Revenue Recognition	11
4. Inventory	12
5. Additional Balance Sheet Information	13
6. Fair Value Measurements	13
7. Derivative Instruments	15
8. Property, Plant and Equipment	17
9. Acquisitions	18
10. Divestitures	18
11. Long-Term Debt	19
12. Asset Retirement Obligations	22
13. Income Taxes	22
14. Equity-Based Compensation	22
15. Stockholders’ Equity	24
16. Earnings (Loss) Per Share	25
17. Business Segment Information	25
18. Commitments and Contingencies	27
19. Subsequent Events	28
Item 2. — Management’s Discussion and Analysis of Financial Condition and Results of Operations	30
Item 3. — Quantitative and Qualitative Disclosures About Market Risk	51
Item 4. — Controls and Procedures	52
PART II — OTHER INFORMATION	53
Item 1. — Legal Proceedings	53
Item 1A. — Risk Factors	53
Item 2. — Unregistered Sales of Equity Securities and Use of Proceeds	54
Item 6. — Exhibits	54
SIGNATURES	56

PART I — FINANCIAL INFORMATION

Item 1. — Financial Statements (Unaudited)

Oasis Petroleum Inc.

Condensed Consolidated Balance Sheets (Unaudited)

	Successor
	September 30, 2021		December 31, 2020
	(In thousands, except share data)
ASSETS
Current assets
Cash and cash equivalents	$	448,608	$	15,856
Restricted cash	—		4,370
Accounts receivable, net	269,740		206,539
Inventory	28,309		33,929
Prepaid expenses	4,274		9,729
Derivative instruments	—		467
Other current assets	2,326		727
Total current assets	753,257		271,617
Property, plant and equipment
Oil and gas properties (successful efforts method)	733,585		810,328
Other property and equipment	962,174		935,950
Less: accumulated depreciation, depletion and amortization	(112,915)		(17,491)
Total property, plant and equipment, net	1,582,844		1,728,787
Restricted cash – non–current	400,000		—
Assets held for sale, net	—		5,500
Derivative instruments	39,717		—
Long-term inventory	17,510		14,522
Operating right-of-use assets	5,115		6,083
Intangible assets	41,624		43,667
Goodwill	70,534		70,534
Other assets	88,911		18,327
Total assets	$	2,999,512	$	2,159,037
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Accounts payable	$	5,522	$	3,242
Revenues and production taxes payable	232,217		146,497
Accrued liabilities	129,000		126,284
Accrued interest payable	26,361		980
Derivative instruments	266,337		56,944
Advances from joint interest partners	1,874		2,723
Current operating lease liabilities	1,914		2,607
Other current liabilities	1,859		1,954
Total current liabilities	665,084		341,231
Long-term debt	1,041,895		710,000
Deferred income taxes	984		984
Asset retirement obligations	45,974		46,363
Derivative instruments	142,516		37,614

1

Operating lease liabilities	1,706		2,362
Other liabilities	8,022		7,744
Total liabilities	1,906,181		1,146,298
Commitments and contingencies (Note 18)	0		0
Stockholders’ equity
Common stock, $0.01 par value: 60,000,000 shares authorized; 20,096,011 shares issued and 19,905,228 shares outstanding at September 30, 2021 and 20,093,017 shares issued and 20,093,017 shares outstanding at December 31, 2020	200		200
Treasury stock, at cost: 190,783 shares at September 30, 2021 and no shares at December 31, 2020	(14,560)		—
Additional paid-in capital	866,992		965,654
Retained earnings (accumulated deficit)	51,810		(49,912)
Oasis share of stockholders’ equity	904,442		915,942
Non-controlling interests	188,889		96,797
Total stockholders’ equity	1,093,331		1,012,739
Total liabilities and stockholders’ equity	$	2,999,512	$	2,159,037

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

2

Oasis Petroleum Inc.

Condensed Consolidated Statements of Operations (Unaudited)

(In thousands, except per share data)

	Successor		Predecessor		Successor		Predecessor
	Three Months Ended September 30, 2021		Three Months Ended September 30, 2020		Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020
Revenues
Oil and gas revenues	$	281,636	$	179,577	$	782,324	$	512,535
Purchased oil and gas sales	53,570		44,194		183,885		167,824
Midstream revenues	66,712		46,979		183,807		138,164
Other services revenues	121		309		542		6,686
Total revenues	402,039		271,059		1,150,558		825,209
Operating expenses
Lease operating expenses	29,307		29,353		98,888		108,730
Midstream expenses	32,396		11,110		83,841		32,355
Other services expenses	26		308		47		5,968
Gathering, processing and transportation expenses	16,400		20,328		52,596		73,557
Purchased oil and gas expenses	53,880		47,549		187,745		165,932
Production taxes	18,445		13,039		50,933		39,129
Depreciation, depletion and amortization	33,623		36,000		112,581		272,885
Exploration expenses	263		725		1,936		3,061
Rig termination	—		1,017		—		1,279
Impairment	—		2,578		5		4,828,575
General and administrative expenses	19,514		49,251		60,461		117,868
Litigation settlement	—		22,750		—		22,750
Total operating expenses	203,854		234,008		649,033		5,672,089
Gain on sale of properties	5,405		1,473		228,473		11,652
Operating income (loss)	203,590		38,524		729,998		(4,835,228)
Other income (expense)
Net gain (loss) on derivative instruments	(101,790)		(5,071)		(550,342)		243,064
Interest expense, net of capitalized interest	(18,153)		(37,389)		(49,421)		(177,534)
Gain (loss) on extinguishment of debt	—		(20)		—		83,867
Reorganization items, net	—		(49,758)		—		(49,758)
Other income (expense)	(315)		1,473		(859)		2,373
Total other income (expense), net	(120,258)		(90,765)		(600,622)		102,012
Income (loss) before income taxes	83,332		(52,241)		129,376		(4,733,216)
Income tax benefit	—		5,144		—		262,495
Net income (loss) including non-controlling interests	83,332		(47,097)		129,376		(4,470,721)
Less: Net income (loss) attributable to non-controlling interests	11,382		8,602		27,654		(11,218)
Net income (loss) attributable to Oasis	$	71,950	$	(55,699)	$	101,722	$	(4,459,503)
Earnings (loss) attributable to Oasis per share:
Basic (Note 16)	$	3.63	$	(0.17)	$	5.11	$	(14.05)
Diluted (Note 16)	3.46		(0.17)		4.96		(14.05)
Weighted average shares outstanding:
Basic (Note 16)	19,812		318,287		19,905		317,365
Diluted (Note 16)	20,786		318,287		20,508		317,365

3

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

4

Oasis Petroleum Inc.

Condensed Consolidated Statements of Changes in Stockholders’ Equity (Deficit)

(Unaudited)

	Attributable to Oasis
	Common Stock			Treasury Stock			Additional Paid-in Capital		Retained Earnings (Accumulated Deficit)		Non-controlling Interests		Total Stockholders’ Equity
	Shares	Amount		Shares	Amount
	(In thousands)
Balance as of December 31, 2020 (Successor)	20,093	$	200	—	$	—	$	965,654	$	(49,912)	$	96,797	$	1,012,739
Equity-based compensation	—	—		—	—		1,709		—		489		2,198
Dividends to shareholders ($0.375 per share)	—	—		—	—		(7,535)		—		—		(7,535)
Distributions to non-controlling interest owners	—	—		—	—		—		—		(6,029)		(6,029)
Midstream Simplification (Note 2)	—	—		—	—		2,358		—		(2,358)		—
Common control transaction costs	—	—		—	—		(4,111)		—		—		(4,111)
Warrants exercised	—	—		—	—		6		—		—		6
Net income (loss)	—	—		—	—		—		(43,592)		8,327		(35,265)
Balance as of March 31, 2021 (Successor)	20,093	200		—	—		958,081		(93,504)		97,226		962,003
Equity-based compensation	—	—		—	—		4,688		—		14		4,702
Dividends to shareholders ($0.375 per share)	—	—		—	—		(8,090)		—		—		(8,090)
Special dividend to shareholders ($4.00 per share)	—	—		—	—		(82,958)		—		—		(82,958)
Distributions to non-controlling interest owners	—	—		—	—		—		—		(6,136)		(6,136)
Repurchase of common stock	(191)	—		191	(14,560)		—		—		—		(14,560)
Issuance of OMP common units, net of offering costs	—	—		—	—		—		—		86,657		86,657
Warrants exercised	2	—		—	—		167		—		—		167
Common control transaction costs	—	—		—	—		(1,321)		—		—		(1,321)
Net income	—	—		—	—		—		73,364		7,945		81,309
Balance as of June 30, 2021 (Successor)	19,904	200		191	(14,560)		870,567		(20,140)		185,706		1,021,773
Equity-based compensation	—	—		—	—		4,143		—		144		4,287
Dividends to shareholders ($0.375 per share)	—	—		—	—		(7,765)		—		—		(7,765)
Distributions to non-controlling interest owners	—	—		—	—		—		—		(8,278)		(8,278)
Warrants exercised	1	—		—	—		68		—		—		68
Common control transaction costs	—	—		—	—		(21)		—		—		(21)
Other	—	—		—	—		—		—		(65)		(65)
Net income	—	—		—	—		—		71,950		11,382		83,332
Balance as of September 30, 2021 (Successor)	19,905	$	200	191	$	(14,560)	$	866,992	$	51,810	$	188,889	$	1,093,331

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

5

Oasis Petroleum Inc.

Condensed Consolidated Statements of Changes in Stockholders’ Equity (Deficit) (Continued)

(Unaudited)

	Attributable to Oasis
	Common Stock			Treasury Stock			Additional Paid-in Capital		Retained Earnings (Accumulated Deficit)		Non-controlling Interests		Total Stockholders’ Equity (Deficit)
	Shares	Amount		Shares	Amount
	(In thousands)
Balance as of December 31, 2019 (Predecessor)	321,231	$	3,189	2,967	$	(33,881)	$	3,112,384	$	554,446	$	200,943	$	3,837,081
Cumulative-effect adjustment for adoption of ASU 2016-13	—	—		—	—		—		(410)		—		(410)
Equity-based compensation	3,836	32		—	—		7,007		—		66		7,105
Distributions to non-controlling interest owners	—	—		—	—		—		—		(6,028)		(6,028)
Equity component of senior unsecured convertible notes, net	—	—		—	—		(337)		—		—		(337)
Treasury stock - tax withholdings	(942)	—		942	(2,308)		—		—		—		(2,308)
Net loss	—	—		—	—		—		(4,310,861)		(23,414)		(4,334,275)
Balance as of March 31, 2020 (Predecessor)	324,125	3,221		3,909	(36,189)		3,119,054		(3,756,825)		171,567		(499,172)
Equity-based compensation	(2,889)	1,018		—	—		3,858		—		66		4,942
Distributions to non-controlling interest owners	—	—		—	—		—		—		(6,014)		(6,014)
Treasury stock - tax withholdings	(252)	—		252	(318)		—		—		—		(318)
Net income (loss)	—	—		—	—		—		(92,943)		3,594		(89,349)
Balance as of June 30, 2020 (Predecessor)	320,984	4,239		4,161	(36,507)		3,122,912		(3,849,768)		169,213		(589,911)
Equity-based compensation	(18)	(1,007)		—	—		5,840		—		69		4,902
Distributions to non-controlling interest owners	—	—		—	—		—		—		(6,020)		(6,020)
Treasury stock - tax withholdings	(35)	—		35	(25)		—		—		—		(25)
Net income (loss)	—	—		—	—		—		(55,699)		8,602		(47,097)
Balance as of September 30, 2020 (Predecessor)	320,931	$	3,232	4,196	$	(36,532)	$	3,128,752	$	(3,905,467)	$	171,864	$	(638,151)

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

6

Oasis Petroleum Inc.

Condensed Consolidated Statements of Cash Flows (Unaudited)

(In thousands)

	Successor		Predecessor
	Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020
Cash flows from operating activities:
Net income (loss) including non-controlling interests	$	129,376	$	(4,470,721)
Adjustments to reconcile net income (loss) including non-controlling interests to net cash provided by operating activities:
Depreciation, depletion and amortization	112,581		272,885
Gain on extinguishment of debt	—		(83,867)
Gain on sale of properties	(228,473)		(11,652)
Impairment	5		4,828,575
Deferred income taxes	—		(262,459)
Derivative instruments	550,342		(243,064)
Equity-based compensation expenses	11,187		16,531
Non-cash reorganization items, net	—		49,758
Deferred financing costs amortization and other	18,811		19,041
Working capital and other changes:
Change in accounts receivable, net	(65,324)		168,749
Change in inventory	2,408		(6,206)
Change in prepaid expenses	4,509		(6,107)
Change in accounts payable, interest payable and accrued liabilities	118,942		(112,479)
Change in other assets and liabilities, net	(9,618)		(4,079)
Net cash provided by operating activities	644,746		154,905
Cash flows from investing activities:
Capital expenditures	(143,201)		(291,776)
Acquisition deposit	(74,500)		—
Proceeds from sale of properties	373,892		15,188
Costs related to sale of properties	(2,785)		—
Derivative settlements	(160,018)		224,223
Derivative modification	(82,419)		—
Net cash used in investing activities	(89,031)		(52,365)
Cash flows from financing activities:
Proceeds from revolving credit facilities	384,500		967,189
Principal payments on revolving credit facilities	(884,500)		(914,549)
Proceeds from issuance of senior unsecured notes	850,000		—
Repurchase of senior unsecured notes	—		(68,060)
Deferred financing costs	(20,480)		(172)
Proceeds from issuance of OMP common units, net of offering costs	86,592		—
Common control transaction costs	(5,453)		—
Purchases of treasury stock	(14,560)		(2,651)
Dividends paid	(102,123)		—
Distributions to non-controlling interests	(20,443)		(18,062)
Payments on finance lease liabilities	(1,107)		(1,989)
Proceeds from warrants exercised	241		—
Net cash provided by (used in) financing activities	272,667		(38,294)
Increase in cash, cash equivalents and restricted cash	828,382		64,246
Cash, cash equivalents and restricted cash:

7

Beginning of period	20,226		20,019
End of period	$	848,608	$	84,265
Supplemental non-cash transactions:
Change in accrued capital expenditures	$	13,014	$	(81,939)
Change in asset retirement obligations	(389)		2,860
Note receivable from divestiture	2,900		—
Contingent consideration from Permian Basin Sale	32,860		—

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

8

Oasis Petroleum Inc.

Notes to Condensed Consolidated Financial Statements (Unaudited)

1. Organization and Operations of the Company

Oasis Petroleum Inc. (together with its consolidated subsidiaries, “Oasis” or the “Company”) is an independent exploration and production (“E&P”) company focused on the acquisition and development of onshore, unconventional crude oil and natural gas resources in the United States. Oasis Petroleum North America LLC (“OPNA”) conducts the Company’s E&P activities and owns its oil and gas properties located in the North Dakota and Montana regions of the Williston Basin. During the second quarter of 2021, the Company sold its E&P assets in the Texas region of the Permian Basin (see Note 10 — Divestitures). In addition to its E&P segment, the Company operates a midstream business segment through Oasis Midstream Partners LP (“OMP”), a gathering and processing master limited partnership that owns, develops, operates and acquires a diversified portfolio of midstream assets in North America.

2. Summary of Significant Accounting Policies

Basis of Presentation

The accompanying unaudited condensed consolidated financial statements of the Company have not been audited by the Company’s independent registered public accounting firm, except that the Condensed Consolidated Balance Sheet at December 31, 2020 is derived from audited financial statements. In the opinion of management, all adjustments, consisting of normal recurring adjustments necessary for the fair statement of the Company’s financial position, have been included. Management has made certain estimates and assumptions that affect reported amounts in the unaudited condensed consolidated financial statements and disclosures of contingencies. Actual results may differ from those estimates. The results for interim periods are not necessarily indicative of annual results.

These interim financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission regarding interim financial reporting. Certain disclosures have been condensed or omitted from these financial statements. Accordingly, they do not include all of the information and notes required by accounting principles generally accepted in the United States of America (“GAAP”) for complete consolidated financial statements and should be read in conjunction with the Company’s audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2020 (“2020 Annual Report”).

Consolidation. The accompanying unaudited condensed consolidated financial statements of the Company include the accounts of Oasis, its wholly-owned subsidiaries and OMP. The Company has determined that the partners with equity at risk in OMP lack the authority, through voting rights or similar rights, to direct the activities that most significantly impact OMP’s economic performance. Therefore, as the limited partners of OMP do not have substantive kick-out or substantive participating rights over its general partner, OMP GP LLC (“OMP GP”), OMP is a variable interest entity. Through the Company’s ownership of OMP GP, the Company has the authority to direct the activities that most significantly affect economic performance and the right to receive benefits that could be potentially significant to OMP. Therefore, the Company is the primary beneficiary and consolidates OMP. The Company records a non-controlling interest for the ownership interest held by public unitholders in OMP. As of September 30, 2021, Oasis owns approximately 70% of OMP. All intercompany balances and transactions have been eliminated upon consolidation.

Midstream Simplification. On March 30, 2021, the Company completed the transactions contemplated by a contribution and simplification agreement (the “Contribution and Simplification Agreement”), dated as of March 22, 2021.

Pursuant to the Contribution and Simplification Agreement, among other things, (a) the Company contributed to OMP its remaining limited liability company interests in Bobcat DevCo LLC (“Bobcat DevCo”) and Beartooth DevCo LLC (“Beartooth DevCo”) of 64.7% and 30.0%, respectively, in exchange for total consideration of approximately $512.5 million composed of (x) a cash distribution of $231.5 million and (y) 12,949,644 common units representing limited partner interests in OMP, (b) OMP’s incentive distribution rights were cancelled and converted into 1,850,356 OMP common units (the “IDR Conversion Common Units”), and (c) OMP GP distributed the IDR Conversion Common Units on a pro rata basis to holders of its Class A Units and Class B Units, such that following such distribution, Oasis, through its wholly-owned subsidiary OMS Holdings LLC (“OMS Holdings”), is the sole member of OMP GP (the foregoing clauses (a), (b) and (c), the “Midstream Simplification”). The effective date of the Midstream Simplification was January 1, 2021.

9

Fresh start accounting. On November 19, 2020 (the “Emergence Date”), the Company emerged from bankruptcy and adopted fresh start accounting in accordance with the Financial Accounting Standards Board’s (“FASB”) Accounting Standards Codification 852, Reorganizations, which resulted in a new basis of accounting and the Company becoming a new entity for financial reporting purposes. As a result of the adoption of fresh start accounting, the condensed consolidated financial statements after the Emergence Date are not comparable to the condensed consolidated financial statements prior to that date. References to “Successor” relate to the reorganized Company’s financial position and results of operations as of and subsequent to the Emergence Date. References to “Predecessor” relate to the Company’s financial position prior to, and results of operations through and including, the Emergence Date.

Risks and Uncertainties

As a crude oil and natural gas producer, the Company’s revenue, profitability and future growth are substantially dependent upon the prevailing and future prices for crude oil and natural gas, which are dependent upon numerous factors beyond its control such as economic, political and regulatory developments and competition from other energy sources. The energy markets have historically been very volatile, and there can be no assurance that crude oil and natural gas prices will not be subject to wide fluctuations in the future. A substantial or extended decline in prices for crude oil and, to a lesser extent, natural gas and natural gas liquids (“NGLs”), could have a material adverse effect on the Company’s financial position, results of operations, cash flows, the quantities of crude oil and natural gas reserves that may be economically produced and the Company’s access to capital.

Cash Equivalents and Restricted Cash

The Company may invest in certain money market funds, commercial paper and time deposits, all of which are stated at fair value or cost which approximates fair value due to the short-term maturity of these investments. The Company classifies all such investments with original maturity dates less than 90 days as cash equivalents.

As of September 30, 2021, restricted cash consisted of proceeds from the Oasis Senior Notes (defined in Note 11 – Long-Term Debt) held in a standalone account to fund a portion of the Williston Basin Acquisition (defined in Note 9 – Acquisitions). As of December 31, 2020, restricted cash consisted of funds that were held in an escrow account for the payment of professional fees associated with the Company’s emergence from bankruptcy.

The following table provides a reconciliation of cash, cash equivalents and restricted cash reported within the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows:

	Successor
	September 30, 2021		December 31, 2020
	(In thousands)
Cash and cash equivalents	$	448,608	$	15,856
Restricted cash	—		4,370
Restricted cash – non–current	400,000		—
Total cash, cash equivalents and restricted cash	$	848,608	$	20,226

Significant Accounting Policies

There have been no material changes to the Company’s critical accounting policies and estimates from those disclosed in the 2020 Annual Report.

Recent Accounting Pronouncements

Reference rate reform. In March 2020, the FASB issued Accounting Standards Update 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting (“ASU 2020-04”). ASU 2020-04 provides optional guidance for a limited time to ease the potential burden in accounting for reference rate reform, including optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria are met. ASU 2020-04 applies only to contracts and hedging relationships that reference the London Interbank Offered Rate (“LIBOR”) or another reference rate expected to be discontinued due to reference rate reform. ASU 2020-04 is effective immediately and may be applied prospectively to contract modifications made and hedging relationships entered into or evaluated on or before December 31, 2022. The Company is currently evaluating its contracts and the optional expedients provided by ASU 2020-04 and the impact the new standard will have on its financial statements and related disclosures.

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3. Revenue Recognition

Exploration and Production Revenues

E&P revenues from contracts with customers for crude oil, natural gas and NGL sales and other services were as follows for the periods presented (in thousands):

	Successor		Predecessor		Successor		Predecessor
	Three Months Ended September 30, 2021		Three Months Ended September 30, 2020		Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020
Crude oil revenues	$	205,731	$	155,052	$	598,278	$	448,904
Purchased crude oil sales	53,562		35,442		163,785		144,719
Natural gas revenues	75,905		24,525		184,046		63,631
Purchased natural gas sales	8		308		362		4,909
Other services revenues	121		309		542		6,686
Total E&P revenues	$	335,327	$	215,636	$	947,013	$	668,849

Midstream Revenues

Midstream revenues are derived from contracts with customers for midstream services under fee-based arrangements and midstream product sales from purchase arrangements. The Company’s midstream revenues exclude intercompany revenues for goods and services provided by the midstream business segment for the Company’s ownership interests, which are eliminated in consolidation.

Revenues derived from contracts with customers for midstream revenues were as follows for the periods presented (in thousands):

	Successor		Predecessor		Successor		Predecessor
	Three Months Ended September 30, 2021		Three Months Ended September 30, 2020		Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020
Midstream service revenues
Crude oil, natural gas and NGL revenues	$	22,111	$	22,682	$	65,225	$	72,267
Produced and flowback water revenues	10,312		8,801		25,230		27,300
Total midstream service revenues	32,423		31,483		90,455		99,567
Midstream product revenues
Purchased crude oil sales(1)	—		8,444		$	19,738	$	18,196
Crude oil, natural gas and NGL revenues	33,845		15,100		91,671		35,707
Freshwater revenues	444		396		1,681		2,890
Total midstream product revenues	34,289		23,940		113,090		56,793
Total midstream revenues	$	66,712	$	55,423	$	203,545	$	156,360

___________________

(1) Reported under purchased oil and gas sales on the Condensed Consolidated Statements of Operations.

Contract Balances

Contract balances are the result of timing differences between revenue recognition, billings and cash collections. Contract assets relate to revenue recognized for accrued deficiency fees associated with minimum volume commitments where the Company believes it is probable there will be a shortfall payment and that a significant reversal of revenue recognized will not occur once the related performance period is completed and the customer is billed. Contract liabilities relate to aid in construction payments received from customers, which are recognized as revenue over the expected period of future benefit. The Company does not recognize contract assets or contract liabilities under its customer contracts for which invoicing occurs once the Company’s performance obligations have been satisfied and payment is unconditional. Contract balances are classified as current or long-term based on when the Company expects to receive cash for contract assets or recognize revenue for contract liabilities. Contract liabilities are included in other current liabilities and other liabilities on the Company’s Condensed Consolidated Balance Sheets. There were no material contract asset balances at September 30, 2021 or December 31, 2020.

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The following table summarizes the changes in the Company’s contract liabilities for the nine months ended September 30, 2021:

	(In thousands)
Balance as of December 31, 2020 (Successor)	$	3,966
Cash received	3,231
Revenues recognized	(276)
Balance as of September 30, 2021 (Successor)	$	6,921

Performance Obligations

The Company records revenue when the performance obligations under the terms of its customer contracts are satisfied. For sales of commodities, the Company records revenue in the month the production or purchased product is delivered to the purchaser. However, settlement statements and payments are typically not received for 20 to 60 days after the date production is delivered, and as a result, the Company is required to estimate the amount of production that was delivered to the purchaser and the price that will be received for the sale of the product. The Company uses knowledge of its properties, its properties’ historical performance, spot market prices and other factors as the basis for these estimates. The Company records the differences between estimates and the actual amounts received for product sales once payment is received from the purchaser. For midstream services, the Company measures the satisfaction of its performance obligations using the output method based upon the volume of crude oil, natural gas or water that flows through its systems. In certain cases, the Company is required to estimate these volumes during a reporting period and record any differences between the estimated volumes and actual volumes in the following reporting period. Differences between estimated and actual revenues have historically not been significant. For the three and nine months ended September 30, 2021 and 2020, revenue recognized related to performance obligations satisfied in prior reporting periods was not material.

Remaining Performance Obligations

The following table presents estimated revenue allocated to remaining performance obligations for contracted revenues that are unsatisfied (or partially satisfied) as of September 30, 2021 (Successor):

	(In thousands)
2021 (excluding the nine months ended September 30, 2021)	$	3,709
2022	17,175
2023	10,896
2024	11,089
2025	2,768
Total	$	45,637

The partially and wholly unsatisfied performance obligations presented in the table above are generally limited to customer contracts which have fixed pricing and fixed volume terms and conditions, which generally include customer contracts with minimum volume commitment payment obligations.

The Company has elected practical expedients, pursuant to Accounting Standards Codification 606, Revenue from Contracts with Customers, to exclude from the presentation of remaining performance obligations: (i) contracts with index-based pricing or variable volume attributes in which such variable consideration is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct service that forms part of a series of distinct services and (ii) contracts with an original expected duration of one year or less.

4. Inventory

The Company’s inventory includes equipment and materials and crude oil inventory. Equipment and materials consist primarily of well equipment, tanks and tubular goods to be used in the Company’s E&P activities and spare parts and equipment for the Company’s midstream assets. Crude oil inventory includes crude oil in tanks and linefill that is expected to be withdrawn within one year. Linefill represents the minimum volume of product in a pipeline system that enables the system to operate and is generally not available to be withdrawn from the pipeline system until the expiration of the transportation contract. Crude oil and NGL linefill in third-party pipelines that is not expected to be withdrawn within one year is included in long-term inventory on the Company’s Condensed Consolidated Balance Sheets.

Inventory, including long-term inventory, is stated at the lower of cost and net realizable value with cost determined on an average cost method. The Company assesses the carrying value of inventory and uses estimates and judgment when making any

12

adjustments necessary to reduce the carrying value to net realizable value. Among the uncertainties that impact the Company’s estimates are the applicable quality and location differentials to include in the Company’s net realizable value analysis as well as the liquidation timing of the inventory. Changes in assumptions made as to the timing of a sale can materially impact net realizable value.

No material write-downs of inventory or long-term inventory were recorded during the three or nine months ended September 30, 2021. There were no write-downs of crude oil inventory or long-term inventory recorded during the three months ended September 30, 2020 (Predecessor). During the nine months ended September 30, 2020 (Predecessor), as a result of lower commodity prices, the Company recorded impairment losses related to the Company’s crude oil inventory and long-term linefill of $7.2 million and $1.3 million, respectively. In addition, during the three and nine months ended September 30, 2020, the Company recorded impairment charges of $0.6 million and $1.6 million, respectively, to write down the carrying value of certain equipment and materials inventory to the estimated net realizable value.

The Company’s total inventory consists of the following:

	Successor
	September 30, 2021		December 31, 2020
	(In thousands)
Inventory
Equipment and materials	$	19,563	$	25,103
Crude oil inventory	8,746		8,826
Total inventory	28,309		33,929
Long-term inventory
Linefill in third party pipelines	17,510		14,522
Total long-term inventory	17,510		14,522
Total	$	45,819	$	48,451

5. Additional Balance Sheet Information

The following table sets forth certain balance sheet amounts comprised of the following:

	Successor
	September 30, 2021		December 31, 2020
	(In thousands)
Accounts receivable, net
Trade accounts	$	200,301	$	161,519
Joint interest accounts	39,291		31,920
Other accounts	31,560		13,206
Total accounts receivable	271,152		206,645
Less: allowance for credit losses	(1,412)		(106)
Total accounts receivable, net	$	269,740	$	206,539
Accrued liabilities
Accrued capital costs	$	51,086	$	39,380
Accrued lease operating expenses	15,257		18,635
Accrued oil and gas purchases	10,467		8,967
Accrued general and administrative expenses	9,964		35,249
Accrued dividends payable	4,224		—
Accrued midstream operating expenses	21,933		15,051
Other accrued liabilities	16,069		9,002
Total accrued liabilities	$	129,000	$	126,284

6. Fair Value Measurements

In accordance with the FASB’s authoritative guidance on fair value measurements, the Company’s financial assets and liabilities are measured at fair value on a recurring basis. The Company’s financial instruments, including certain cash and cash equivalents, accounts receivable, accounts payable and other payables, are carried at cost, which approximates their respective

13

fair market values due to their short-term maturities. The Company recognizes its non-financial assets and liabilities, such as asset retirement obligations (“ARO”) and properties acquired in a business combination or upon impairment, at fair value on a non-recurring basis.

As defined in the authoritative guidance, fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). To estimate fair value, the Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable.

The authoritative guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (“Level 1” measurements) and the lowest priority to unobservable inputs (“Level 3” measurements). The three levels of the fair value hierarchy are as follows:

Level 1 — Unadjusted quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2 — Pricing inputs, other than unadjusted quoted prices in active markets included in Level 1, are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace.

Level 3 — Pricing inputs are generally unobservable from objective sources, requiring internally developed valuation methodologies that result in management’s best estimate of fair value.

Financial Assets and Liabilities

Financial assets and liabilities are classified in their entirety 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 requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

The following tables set forth by level, within the fair value hierarchy, the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis:

	Successor
	Fair value at September 30, 2021
	Level 1		Level 2		Level 3		Total
	(In thousands)
Assets:
Permian Basin Sale Contingent Consideration	$	—	$	39,717	$	—	$	39,717
Total assets	$	—	$	39,717	$	—	$	39,717
Liabilities:
Commodity derivative instruments	$	—	$	408,853	$	—	$	408,853
Total liabilities	$	—	$	408,853	$	—	$	408,853

	Successor
	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
	(In thousands)
Assets:
Commodity derivative instruments	$	—	$	467	$	—	$	467
Total assets	$	—	$	467	$	—	$	467
Liabilities:
Commodity derivative instruments	$	—	$	94,558	$	—	$	94,558
Total liabilities	$	—	$	94,558	$	—	$	94,558

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Commodity derivative instruments. The fair value of the Company’s commodity derivative instruments is based upon a third-party preparer’s calculation using mark-to-market valuation reports provided by the Company’s counterparties for monthly settlement purposes to determine the valuation of its derivative instruments. The Company has the third-party preparer evaluate other readily available market prices for its derivative contracts, as there is an active market for these contracts. The third-party preparer performs its independent valuation using a moment matching method similar to Turnbull-Wakeman for Asian options. The significant inputs used are commodity prices, volatility, skew, discount rate and the contract terms of the derivative instruments. The Company does not have access to the specific proprietary valuation models or inputs used by its counterparties or the third-party preparer. The Company compares the third-party preparer’s valuation to counterparty valuation statements, investigating any significant differences, and analyzes monthly valuation changes in relation to movements in forward commodity price curves. The determination of the fair value for derivative instruments also incorporates a credit adjustment for non-performance risk, as required by GAAP. The Company calculates the credit adjustment for derivatives in a net asset position using current credit default swap values for each counterparty. The credit adjustment for derivatives in a net liability position is based on the market credit spread of the Company or similarly rated public issuers. The Company recorded an adjustment to reduce the fair value of its net derivative liability by $8.7 million and $4.3 million at September 30, 2021 and December 31, 2020, respectively. See Note 7 – Derivative Instruments for more information.

Permian Basin Sale Contingent Consideration. The fair value of the Permian Basin Sale Contingent Consideration (defined in Note 7 – Derivative Instruments) was determined by a third-party valuation specialist as of the close date using a Monte Carlo simulation model and Ornstein-Uhlenbeck pricing process. The significant inputs include NYMEX West Texas Intermediate crude oil price index (“NYMEX WTI”) forward price curve, volatility, mean reversion rate and counterparty credit risk adjustment. The Company determined these were Level 2 fair value inputs that are substantially observable in active markets or can be derived from observable data. See Note 7 – Derivative Instruments and Note 10 – Divestitures for more information.

Non-Financial Assets and Liabilities

The fair value of the Company’s non-financial assets measured at fair value on a non-recurring basis is determined using valuation techniques that include Level 3 inputs.

Asset retirement obligations. The initial measurement of ARO at fair value is recorded in the period in which the liability is incurred. Fair value is determined by calculating the present value of estimated future cash flows related to the liability. Estimating the future ARO requires management to make estimates and judgments regarding the timing and existence of a liability, as well as what constitutes adequate restoration when considering current regulatory requirements. Inherent in the fair value calculation are numerous assumptions and judgments, including the ultimate costs, inflation factors, credit-adjusted discount rates, timing of settlement and changes in the legal, regulatory, environmental and political environments.

7. Derivative Instruments

The Company utilizes derivative financial instruments to manage risks related to changes in crude oil and natural gas prices. The Company’s crude oil contracts settle monthly based on the average NYMEX WTI, and its natural gas contracts settle monthly based on the average NYMEX Henry Hub natural gas index price (“NYMEX HH”).

The Company primarily utilizes fixed price swaps and collars to reduce the volatility of crude oil and natural gas prices on future expected production. Swaps are designed to establish a fixed price for the volumes under contract, while collars are designed to establish a minimum price (floor) and a maximum price (ceiling) for the volumes under contract. The Company may, from time to time, restructure existing derivative contracts or enter into new transactions to effectively modify the terms of current contracts in order to improve the pricing parameters in existing contracts.

All derivative instruments are recorded on the Company’s Condensed Consolidated Balance Sheets as either assets or liabilities measured at fair value (see Note 6 – Fair Value Measurements). The Company has not designated any derivative instruments as hedges for accounting purposes and does not enter into such instruments for speculative trading purposes. If a derivative does not qualify as a hedge or is not designated as a hedge, the changes in fair value are recognized in the other income (expense) section of the Company’s Condensed Consolidated Statements of Operations as a net gain or loss on derivative instruments. Derivative settlements are reflected as investing activities on the Company’s Condensed Consolidated Statements of Cash Flows and represent net cash payments to or receipts from counterparties upon the maturity or liquidation of a derivative contract.

On March 22, 2021, the Company entered into the Second Amendment to the Oasis Credit Facility (as defined in Note 11 –Long-Term Debt) to, among other things, reduce the rolling hedging requirement and add incremental flexibility to allow for restructuring of existing hedge positions (see Note 11 – Long-Term Debt).

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On May 17, 2021, the Company entered into a series of transactions with derivative counterparties to modify the swap price of certain commodity hedge contracts to $50.00 per barrel based on NYMEX WTI from weighted average prices of $40.72 per barrel, $43.57 per barrel and $43.68 per barrel for 2022, 2023 and 2024, respectively. The commodity contracts modified included total notional volumes of 6,346,000 barrels, 5,265,000 barrels and 434,000 barrels which settle in 2022, 2023 and 2024, respectively. The Company paid $82.4 million for the modification of these commodity derivative contracts, which is reflected as a cash outflow from investing activities in the Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2021.

At September 30, 2021 (Successor), the Company had the following outstanding commodity derivative instruments:

Commodity	Settlement Period	Derivative Instrument	Volumes			Weighted Average Prices						Fair Value Assets (Liabilities)
					Fixed Price Swaps			Floor			Ceiling
												(In thousands)
Crude oil	2021	Fixed price swaps	2,639,000	Bbl		$	42.09							$	(83,180)
Crude oil	2021	Two-way collar	728,000	Bbl					$	51.25		$	68.24	(4,343)
Crude oil	2022	Fixed price swaps	7,245,000	Bbl		$	49.02							(155,383)
Crude oil	2022	Two-way collar	4,799,000	Bbl					$	49.50		$	66.62	(38,493)
Crude oil	2023	Fixed price swaps	5,265,000	Bbl		$	50.00							(73,146)
Crude oil	2023	Two-way collar	4,380,000	Bbl					$	45.42		$	65.05	(25,702)
Crude oil	2024	Fixed price swaps	434,000	Bbl		$	50.00							(4,811)
Crude oil	2024	Two-way collar	372,000	Bbl					$	45.00		$	64.88	(1,586)
Natural gas	2021	Fixed price swaps	3,680,000	MMBtu		$	2.84							(11,222)
Natural gas	2022	Fixed price swaps	5,430,000	MMBtu		$	2.82							(10,987)
														$	(408,853)

Permian Basin Sale Contingent Consideration. Pursuant to the Primary Permian Basin Sale PSA (defined in Note 10 – Divestitures), the Company is entitled to receive up to three earn-out payments of $25.0 million per year for each of 2023, 2024 and 2025 if the average daily settlement price of NYMEX WTI crude oil exceeds $60 per barrel for such year (the “Permian Basin Sale Contingent Consideration”). If the NYMEX WTI crude oil price for calendar year 2023 or 2024 is less than $45 per barrel, then each calendar year thereafter the buyer’s obligation to make any remaining earn-out payments is terminated. The Company determined that the Permian Basin Sale Contingent Consideration was an embedded derivative in accordance with the FASB Accounting Standards Codification 815, Derivatives and Hedging. The Company bifurcated the Permian Basin Sale Contingent Consideration from the host contract and accounted for it separately at fair value. The fair value of the Permian Basin Sale Contingent Consideration was estimated to be $32.9 million as of the close date on June 29, 2021. The Permian Basin Sale Contingent Consideration is marked-to-market each reporting period, with changes in fair value recognized as a net gain or loss on derivative instruments in other income (expense) on the Condensed Consolidated Statements of Operations. As of September 30, 2021, the estimated fair value of the Permian Basin Sale Contingent Consideration was $39.7 million, which was classified as a non-current derivative asset on the Condensed Consolidated Balance Sheet. See Note 6 – Fair Value Measurements and Note 10 – Divestitures for additional information.

The following table summarizes the location and amounts of gains and losses from the Company’s derivative instruments recorded in the Company’s Condensed Consolidated Statements of Operations for the periods presented (in thousands):

		Successor		Predecessor		Successor		Predecessor
		Three Months Ended September 30, 2021		Three Months Ended September 30, 2020		Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020
Derivative Instrument	Statements of Operations Location
Commodity derivative instruments	Net gain (loss) on derivative instruments	$	(108,647)	$	(5,071)	$	(557,199)	$	243,064
Contingent consideration	Net gain on derivative instruments	6,857		—		6,857		—
Contingent consideration	Gain on sale of properties	—		—		32,860		—

In accordance with the FASB’s authoritative guidance on disclosures about offsetting assets and liabilities, the Company is required to disclose both gross and net information about instruments and transactions eligible for offset in the statement of financial position as well as instruments and transactions subject to an agreement similar to a master netting agreement. The Company’s derivative instruments are presented as assets and liabilities on a net basis by counterparty, as all counterparty

16

contracts provide for net settlement. No margin or collateral balances are deposited with counterparties, and as such, gross amounts are offset to determine the net amounts presented in the Company’s Condensed Consolidated Balance Sheets.

The following table summarizes the location and fair value of all outstanding derivative instruments recorded in the Company’s Condensed Consolidated Balance Sheets:

 

		Successor
		September 30, 2021
Derivative Instrument	Balance Sheet Location	Gross Amount		Gross Amount Offset		Net Amount
		(In thousands)
Derivatives assets:
Contingent consideration	Derivative instruments — non-current assets	$	39,717	$	—	$	39,717
Derivatives liabilities:
Commodity contracts	Derivative instruments — current liabilities	$	271,077	$	(4,740)	$	266,337
Commodity contracts	Derivative instruments — non-current liabilities	164,614		(22,098)		142,516
Total derivatives liabilities		$	435,691	$	(26,838)	$	408,853
		Successor
		December 31, 2020
Derivative Instrument	Balance Sheet Location	Gross Amount		Gross Amount Offset		Net Amount
		(In thousands)
Derivatives assets:
Commodity contracts	Derivative instruments — current assets	$	467	$	—	$	467
Derivatives liabilities:
Commodity contracts	Derivative instruments — current liabilities	$	59,262	$	(2,318)	$	56,944
Commodity contracts	Derivative instruments — non-current liabilities	38,426		(812)		37,614
Total derivatives liabilities		$	97,688	$	(3,130)	$	94,558

8. Property, Plant and Equipment

The following table sets forth the Company’s property, plant and equipment:

	Successor
	September 30, 2021		December 31, 2020
	(In thousands)
Proved oil and gas properties	$	731,292	$	770,117
Less: Accumulated depreciation, depletion and amortization	(70,343)		(12,403)
Proved oil and gas properties, net	660,949		757,714
Unproved oil and gas properties	2,293		40,211
Other property and equipment	962,174		935,950
Less: Accumulated depreciation	(42,572)		(5,088)
Other property and equipment, net	919,602		930,862
Total property, plant and equipment, net	$	1,582,844	$	1,728,787

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9. Acquisitions

Williston Basin Acquisition. On May 3, 2021, the Company entered into a purchase and sale agreement with QEP Energy Company (“QEP”), a wholly-owned subsidiary of Diamondback Energy, Inc., to acquire approximately 95,000 net acres in the Williston Basin, effective April 1, 2021, for an aggregate purchase price of $745.0 million, subject to customary purchase price adjustments (the “Williston Basin Acquisition”). The adjusted purchase price was $585.8 million, comprised of a deposit of $74.5 million paid on May 3, 2021 and $511.3 million paid at closing on October 21, 2021. The adjusted purchase price included customary purchase price adjustments, primarily related to the net cash flows from the effective date to the closing date. The Company funded the Williston Basin Acquisition with cash on hand, including proceeds from the Permian Basin Sale (defined in Note 10 – Divestitures) and the Oasis Senior Notes (defined in Note 11 – Long-Term Debt).

The Company is currently evaluating whether the Williston Basin Acquisition qualifies as a business combination or asset acquisition. The Company has engaged a third party valuation specialist and expects to complete the accounting in the fourth quarter of 2021.

10. Divestitures

Permian Basin Sale. On May 20, 2021, Oasis Petroleum Permian LLC (“OPP”), a wholly-owned subsidiary of the Company, entered into a purchase and sale agreement (the “Primary Permian Basin Sale PSA”) with Percussion Petroleum Operating II, LLC (“Percussion”). Pursuant to the Primary Permian Basin Sale PSA, OPP agreed to sell to Percussion its remaining upstream assets in the Texas region of the Permian Basin with an effective date of March 1, 2021 for an aggregate purchase price of $450.0 million (the “Primary Permian Basin Sale”). The aggregate purchase price consists of $375.0 million cash at closing and up to three earn-out payments of $25.0 million per year for each of 2023, 2024 and 2025 if the average daily settlement price of NYMEX WTI crude oil exceeds $60.00 per barrel for such year.

On June 29, 2021, the Company completed the Primary Permian Basin Sale and received cash proceeds (after purchase price adjustments) of $347.3 million. In addition to the Primary Permian Basin Sale, the Company divested certain wellbore interests in the Texas region of the Permian Basin to separate buyers in the second quarter of 2021 and received cash proceeds (after purchase price adjustments) of $24.0 million (the “Additional Permian Basin Sale” and together with the Primary Permian Basin Sale, the “Permian Basin Sale”). The assets divested in the Permian Basin Sale were in the Company’s E&P segment.

During the three and nine months ended September 30, 2021, the Company recorded income before income taxes related to the Permian Basin Sale assets of $5.9 million and $268.1 million, respectively, which included a gain on sale of properties of $4.9 million and $227.4 million, respectively. During the three and nine months ended September 30, 2020 (Predecessor), the Company recorded income before income taxes related to the assets divested in the Permian Basin Sale of $12.1 million and loss before income taxes of $883.0 million, respectively.

The Company accounted for revenues and expenses related to assets divested in the Permian Basin Sale as income from continuing operations in the Condensed Consolidated Statements of Operations because the Permian Basin Sale did not cause a strategic shift for the Company and as a result, did not qualify as discontinued operations under FASB Accounting Standards Codification 205-20, Presentation of financial statements – Discontinued Operations.

Other. On March 22, 2021, the Company completed the sale of certain well services equipment and inventory in connection with its 2020 exit from the well services business for total consideration of $5.5 million, comprised of cash proceeds of $2.6 million and a $2.9 million 6.6% promissory note due within one year, which is included in other current assets in the Condensed Consolidated Balance Sheet. The divested well services equipment and inventory were in the Company’s E&P segment.

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11. Long-Term Debt

The Company’s long-term debt consists of the following:

	Successor
	September 30, 2021		December 31, 2020
	(In thousands)
Oasis Credit Facility	$	—	$	260,000
Oasis Senior Notes	400,000		—
Less: unamortized deferred financing costs on Oasis Senior Notes	(8,495)		—
Total Oasis Guarantors	391,505		260,000
OMP Credit Facility	210,000		450,000
OMP Senior Notes	450,000		—
Less: unamortized deferred financing costs on OMP Senior Notes	(9,610)		—
Total unrestricted subsidiaries	650,390		450,000
Total long-term debt, net	$	1,041,895	$	710,000

Oasis Debt

Oasis Credit Facility

The Company has a senior secured revolving credit facility (the “Oasis Credit Facility”) among Oasis Petroleum Inc., as parent, OPNA, as borrower, and Wells Fargo Bank, N.A. (“Wells Fargo”), as administrative agent and the lenders party thereto, which has a maturity date of May 19, 2024.

On March 22, 2021, the Company entered into the Second Amendment to the Oasis Credit Facility to, among other things, (i) provide for the occurrence of the transactions pursuant to the Midstream Simplification, (ii) decrease the borrowing base from $575.0 million to $500.0 million, (iii) decrease the aggregate lender commitments from $575.0 million to $450.0 million, (iv) provide the ability to initiate certain share-repurchases, (v) reduce the rolling hedging requirement and add incremental flexibility to allow for restructuring of existing hedge positions and (vi) decrease the LIBOR floor from 1.00% to 0.25%.

On May 3, 2021, the Company entered into the Third Amendment to the Oasis Credit Facility to, among other things, (i) provide the ability to incur loans pursuant to a customary bridge loan facility, (ii) add customary terms allowing for the incurrence of second liens, (iii) eliminate restrictions on the ability to make deposits of cash and/or cash equivalents in connection with any letter of intent or purchase agreement for certain acquisitions or investments, (iv) remove limitations on the making of capital expenditures and (v) provide for improvements and conforming changes to terms to facilitate acquisitions and investments.

On May 21, 2021, the Company entered into the Fourth Amendment to the Oasis Credit Facility (the “Fourth Amendment”) to, among other things, (i) provide that no borrowing base reduction shall occur in connection with any issuance of senior notes in an aggregate principal amount not in excess of $550.0 million issued after the effective date of the Fourth Amendment and prior to the effectiveness of the scheduled redetermination to occur on or about October 1, 2021, (ii) reduce the borrowing base by $100.0 million upon consummation of the Primary Permian Basin Sale and (iii) increase the borrowing base by $250.0 million upon consummation of the Williston Basin Acquisition. The borrowing base increased to $900.0 million after the Company completed the semi-annual redetermination of the borrowing base on October 21, 2021 in connection with the Fifth Amendment (defined below). The Fourth Amendment also amends the exceptions from the restricted payments negative covenant to provide increased restricted payment flexibility, permitting unlimited restricted payments subject to (x) no event of default under the Oasis Credit Facility, (y) at least 25% availability under the Oasis Credit Facility and (z) the pro forma leverage ratio being not more than 1.5 to 1.0; provided that if the conditions described in clauses (x) and (y) are satisfied and the pro forma leverage ratio is less than 2.0 to 1.0, but more than 1.5 to 1.0, restricted payments are permitted in an amount such that all restricted payments made in reliance on such exception since the closing date of the Oasis Credit Facility will not exceed the positive amount of free cash flow.

On October 21, 2021, the Company entered into the Fifth Amendment to the Oasis Credit Facility (the “Fifth Amendment”). In connection with the Fifth Amendment, the semi-annual redetermination of the Company’s borrowing base was completed which, effective October 21, 2021, increased the borrowing base to $900.0 million and reaffirmed the aggregated lender commitments of $450.0 million.

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At September 30, 2021, the Company had no borrowings outstanding and $1.3 million of outstanding letters of credit under the Oasis Credit Facility, resulting in an unused borrowing capacity of $398.7 million. During the three months ended September 30, 2021, there were no borrowings outstanding under the Oasis Credit Facility. For the nine months ended September 30, 2021, the weighted average interest rate incurred on borrowings under the Oasis Credit Facility was 4.2%. The fair value of the Oasis Credit Facility approximates its carrying value since borrowings under the Oasis Credit Facility bear interest at variable rates, which are tied to current market rates.

The Oasis Credit Facility contains customary events of default, as well as cross-default provisions with other indebtedness of OPNA and the restricted subsidiaries under the Oasis Credit Facility. If an event of default occurs and is continuing, the lenders may declare all amounts outstanding under the Oasis Credit Facility to be immediately due and payable. There are no cross-default provisions between the Oasis Credit Facility and the indebtedness of OMP and its restricted subsidiaries that are applicable subsequent to the Midstream Simplification. The Company was in compliance with the financial covenants under the Oasis Credit Facility at September 30, 2021.

Oasis Bridge Facility

On May 3, 2021, the Company entered into a commitment letter with J.P. Morgan Chase Bank, N.A., Wells Fargo and Wells Fargo Securities, LLC (the “Arrangers”) pursuant to which the Arrangers committed to provide the Company a $500.0 million senior secured second lien facility (the “Oasis Bridge Facility”) to partially finance the transactions contemplated by the Williston Basin Acquisition. Prior to being drawn, the Oasis Bridge Facility was replaced with the Oasis Senior Notes (defined below), which terminated all obligations under the Oasis Bridge Facility. During the nine months ended September 30, 2021, the Company incurred aggregate fees in connection with the Oasis Bridge Facility of $7.8 million, which were recorded to interest expense on the Company’s Condensed Consolidated Statement of Operations. No fees were incurred during the three months ended September 30, 2021.

Oasis Senior Notes

On June 9, 2021, the Company issued in a private placement $400.0 million of 6.375% senior unsecured notes due June 1, 2026 (the “Oasis Senior Notes”). The Oasis Senior Notes were issued at par and resulted in net proceeds of $393.0 million, after deducting the underwriters’ discounts and commissions. The proceeds were held in a standalone bank account at September 30, 2021 and were used to fund a portion of the consideration for the Williston Basin Acquisition upon its completion on October 21, 2021 (see Note 9 – Acquisitions).

In connection with the issuance of the Oasis Senior Notes, the Company recorded deferred financing costs of $9.0 million, which are being amortized over the term of the notes. The fair value of the Oasis Senior Notes, which are publicly traded among qualified institutional investors and represent a Level 1 fair value measurement, was $419.0 million at September 30, 2021.

Interest on the Oasis Senior Notes is payable semi-annually on June 1 and December 1 of each year, commencing on December 1, 2021. The Oasis Senior Notes are guaranteed on a senior unsecured basis by the Company, along with its wholly-owned subsidiaries (the “Oasis Guarantors”). These guarantees are full and unconditional and joint and several among the Oasis Guarantors, subject to certain customary release provisions. The indentures governing the Oasis Senior Notes contain customary events of default. In addition, the indenture governing the Oasis Senior Notes contains cross-default provisions with other indebtedness of Oasis and its restricted subsidiaries; however, there are no cross-default provisions with the indebtedness of OMP and its restricted subsidiaries.

The indentures governing the Oasis Senior Notes restrict the Company’s ability and the ability of certain of its subsidiaries to, among other things: (i) make investments; (ii) incur additional indebtedness or issue preferred stock; (iii) create liens; (iv) sell assets; (v) enter into agreements that restrict dividends or other payments by restricted subsidiaries; (vi) consolidate, merge or transfer all or substantially all of the Company’s assets with another company; (vii) enter into transactions with affiliates; (viii) pay dividends or make other distributions on capital stock or prepay subordinated indebtedness; and (ix) create unrestricted subsidiaries. These covenants are subject to a number of important exceptions and qualifications. If at any time when the Oasis Senior Notes are rated investment grade by two out of the three rating agencies and no default (as defined in the indentures) has occurred and is continuing, many of such covenants will terminate and the Company will cease to be subject to such covenants. The Company was in compliance with the terms of the indentures for the Oasis Senior Notes as of September 30, 2021.

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OMP Debt

OMP Credit Facility

OMP has a senior secured revolving credit facility (the “OMP Credit Facility”) among OMP, as parent, OMP Operating LLC, as borrower, Wells Fargo, as administrative agent and the lenders party thereto. On March 22, 2021, OMP entered into the Fourth Amendment to the OMP Credit Facility (the “OMP Credit Facility Fourth Amendment”) to, among other things, (i) provide for the occurrence of the transactions pursuant to the Midstream Simplification, (ii) amend the consolidated total leverage ratio financial covenant to no greater than 5.00 to 1.00, (iii) amend the consolidated senior secured leverage ratio to no greater than 3.00 to 1.00, (iv) amend the consolidated interest coverage ratio to no less than 2.50 to 1.00, (v) provide for the issuance of the OMP Senior Notes (defined below), (vi) decrease the aggregate lender commitments from $575.0 million to $450.0 million, (vii) increase pricing for credit under the OMP Credit Facility and (viii) extend the maturity date from September 25, 2022 until at least September 30, 2024.

Following the OMP Credit Facility Fourth Amendment, the applicable margin for borrowings under the OMP Credit Facility varies from (a) in the case of LIBOR loans (defined in the OMP Credit Facility as Eurodollar Loans), 2.25% to 3.25%, and (b) in the case of domestic bank prime rate interest loans (defined in the OMP Credit Facility as ABR Loans) or swingline loans, 1.25% to 2.25%. The unused portion of the OMP Credit Facility is subject to a commitment fee ranging from 0.375% to 0.500%.

At September 30, 2021, the aggregate amount of elected commitments under the OMP Credit Facility was $450.0 million, and there were $210.0 million of borrowings outstanding and $5.5 million of outstanding letters of credit, resulting in an unused borrowing capacity of $234.5 million. For the three and nine months ended September 30, 2021, the weighted average interest rate incurred on borrowings under the OMP Credit Facility was 2.5% and 2.4%, respectively. The fair value of the OMP Credit Facility approximates its carrying value since borrowings under the OMP Credit Facility bear interest at variable rates, which are tied to current market rates.

The OMP Credit Facility contains customary events of default, as well as cross-default provisions with other indebtedness of OMP and the restricted subsidiaries under the OMP Credit Facility. If an event of default occurs and is continuing, the lenders may declare all amounts outstanding under the OMP Credit Facility to be immediately due and payable. There are no cross-default provisions between the OMP Credit Facility and the indebtedness of Oasis and its restricted subsidiaries. OMP was in compliance with the financial covenants under the OMP Credit Facility at September 30, 2021.

OMP Senior Notes

On March 30, 2021, OMP and OMP Finance Corp. (“OMP Finance” and together with OMP, the “OMP Issuers”) issued in a private placement $450.0 million of 8.00% senior unsecured notes due April 1, 2029 (the “OMP Senior Notes”). The OMP Senior Notes were issued at par and resulted in net proceeds, after deducting the underwriters’ gross spread, of $442.1 million. OMP used the net proceeds from the OMP Senior Notes to: (i) make a distribution to OMS Holdings of $231.5 million in connection with the Midstream Simplification, (ii) repay $204.0 million of outstanding principal borrowings and $0.5 million of accrued interest under the OMP Credit Facility and (iii) pay approximately $6.1 million in fees and other expenses. In connection with the issuance of the OMP Senior Notes, OMP recorded deferred financing costs of $10.2 million, which are being amortized over the term of the notes. The fair value of the OMP Senior Notes, which are publicly traded among qualified institutional investors and represent a Level 1 fair value measurement, was $468.0 million at September 30, 2021.

Interest on the OMP Senior Notes is payable semi-annually on April 1 and October 1 of each year, commencing on October 1, 2021. The OMP Senior Notes are fully and unconditionally guaranteed on a senior unsecured basis by the OMP Issuers, along with OMP’s wholly-owned subsidiaries (the “OMP Guarantors”). The OMP Senior Notes guarantees are joint and several obligations of the OMP Guarantors. The OMP Issuers and the OMP Guarantors do not have any significant restrictions on the ability to obtain funds from its subsidiaries by dividend or loan. In addition, there are no restrictions on the subsidiaries to transfer funds, and as such, there are no restricted net assets to disclose.

The indenture governing the OMP Senior Notes contains certain covenants that, subject to certain exceptions and qualifications, among other things, limit OMP’s ability and the ability of its restricted subsidiaries to, among other things: (i) incur or guarantee additional indebtedness or issue certain redeemable or preferred equity, (ii) make certain investments, (iii) declare or pay dividends or make distributions on equity interests or redeem, repurchase or retire equity interests or subordinated indebtedness, (iv) transfer or sell assets including equity of restricted subsidiaries, (v) agree to payment restrictions affecting OMP’s restricted subsidiaries, (vi) consolidate, merge, sell or otherwise dispose of all or substantially all of its assets, (vii) enter into transactions with affiliates, (viii) incur liens and (ix) designate certain of OMP’s subsidiaries as unrestricted subsidiaries. The indenture governing the OMP Senior Notes contains cross-default provisions with other indebtedness of OMP and its restricted subsidiaries; however, there are no cross-default provisions with the indebtedness of Oasis and its restricted subsidiaries.

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12. Asset Retirement Obligations

The following table reflects the changes in the Company’s ARO during the nine months ended September 30, 2021:

	(In thousands)
Balance at December 31, 2020 (Successor)	$	48,594
Liabilities incurred during period	409
Liabilities settled during period	(322)
Accretion expense during period	3,016
Revisions to estimates	194
Liabilities settled through divestitures	(4,844)
Balance at September 30, 2021 (Successor)	$	47,047

Accretion expense is included in depreciation, depletion and amortization on the Company’s Condensed Consolidated Statements of Operations. At September 30, 2021 and December 31, 2020, the current portion of the total ARO balance was $1.1 million and $2.2 million, respectively, and is included in accrued liabilities on the Company’s Condensed Consolidated Balance Sheets.

13. Income Taxes

The Company’s effective tax rate for both the three and nine months ended September 30, 2021 (Successor) was 0.0%. The Company’s effective tax rates for the three and nine months ended September 30, 2020 (Predecessor) were 9.8% and 5.5%, respectively.

The effective tax rates for the three and nine months ended September 30, 2021 and 2020 were lower than the statutory federal rate of 21% primarily as a result of the Company’s valuation allowance, which was initially recorded against substantially all of the Company’s net deferred tax assets as of March 31, 2020 and was maintained as of September 30, 2021.

The Company’s estimated valuation allowance as of September 30, 2021 was $529.8 million, which decreased $35.6 million from $565.4 million as of December 31, 2020. The Company concluded it is more likely than not that some or all of the benefits from its deferred tax assets will not be realized, and as such, recorded a valuation allowance on these assets. Management assesses the available positive and negative evidence, including future reversals of temporary differences, tax-planning strategies and future taxable income, to estimate whether sufficient future taxable income will be generated to permit the use of deferred tax assets. If the Company concludes it is more likely than not that a portion, or all, of its deferred tax assets will not be realized, the deferred tax asset is reduced by a valuation allowance. A significant piece of objective negative evidence evaluated is the cumulative loss incurred over recent years, excluding the impact of the voluntary restructuring under Chapter 11 of the Bankruptcy Code in 2020. Such objective negative evidence limits the ability to consider other subjective positive evidence. The amount of the deferred tax asset considered realizable could be adjusted if estimates of future taxable income change or if objective negative evidence, in the form of cumulative losses, is no longer present and additional weight is given to subjective evidence such as future growth. The Company evaluates the appropriateness of its valuation allowance on a quarterly basis.

Upon emergence from bankruptcy, the Company experienced an “ownership change” as defined by Section 382 of the Internal Revenue Code of 1986, as amended (the “Code”). Under Section 382 of the Code, the Company’s net operating loss carryforwards and other tax attributes (collectively, the “Tax Benefits”) are potentially subject to various limitations going forward. Prior to June 30, 2021, the Company had not determined whether it would be eligible for, and would utilize the exception under Section 382(l)(5) of the Code, which allows for no limitations going forward; accordingly, the limitation was previously determined under Section 382(l)(6) of the Code. After additional consideration and review, the Company concluded it qualifies for treatment under Section 382(l)(5) of the Code and utilized this exception with the filing of its 2020 tax return. As a result, the Company expects to owe no cash taxes for the 2021 tax year. Prior to determining it could utilize the exception under Section 382(l)(5) of the Code, the Company made an estimated income tax payment of $20.0 million during the second quarter of 2021, which the Company expects to be refunded in the first quarter of 2022. This refund amount of $20.0 million is recorded under accounts receivable, net on the Condensed Consolidated Balance Sheet at September 30, 2021.

14. Equity-Based Compensation

Successor Equity-Based Compensation

The Compensation Committee of the Board of Directors approved the grant of certain awards under the Company’s 2020 Long Term Incentive Plan (“2020 LTIP”), which consists of restricted stock units (“RSUs”), performance share units (“PSUs”) and leveraged stock units (“LSUs”). The Company accounts for RSUs, PSUs and LSUs as equity classified awards in accordance with the FASB’s authoritative guidance for share-based payments.

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Restricted stock units. RSUs are contingent shares that are scheduled to vest 25% each year over a four-year period to promote retention of key employees. The fair value is based on the closing price of the Company’s common stock on the date of grant or, if applicable, the date of modification. Compensation expense is recognized ratably over the requisite service period. During the nine months ended September 30, 2021, the Company granted 443,836 RSUs with a weighted average grant date per share value of $51.64. During the three and nine months ended September 30, 2021, the Company recorded equity-based compensation expense related to RSUs of $1.4 million and $3.5 million, respectively, in general and administrative expenses on its Condensed Consolidated Statements of Operations.

Performance share units. PSUs are contingent shares that may be earned over three-year and four-year performance periods. The number of PSUs to be earned is subject to a market condition, which is based on a comparison of the total shareholder return (“TSR”) achieved with respect to shares of the Company’s common stock against the TSR achieved by a defined peer group at the end of the applicable performance periods, with 50% of the PSU awards eligible to be earned based on performance relative to a certain group of the Company’s oil and gas peers and 50% of the PSU awards eligible to be earned based on performance relative to the broad-based Russell 2000 index. Depending on the Company’s TSR performance relative to the defined peer group, award recipients may earn between 0% and 150% of target.

During the nine months ended September 30, 2021, the Company granted 183,915 PSUs with a weighted average grant date per share value of $63.95. During the three and nine months ended September 30, 2021, the Company recorded equity-based compensation expense related to PSUs of $0.9 million and $2.2 million, respectively, in general and administrative expenses on its Condensed Consolidated Statements of Operations.

Leveraged stock units. LSUs are contingent shares that may be earned over a three-year or four-year performance period. The number of LSUs to be earned is subject to a market condition, which is based on the TSR performance of the Company’s common stock measured against specific premium return objectives. Depending on the Company’s TSR performance, award recipients may earn between 0% and 300% of target; however, the number of shares delivered in respect to these awards during the grant cycle may not exceed ten times the fair value of the award on the grant date.

During the nine months ended September 30, 2021, the Company granted 262,406 LSUs with a weighted average grant date per share value of $78.79. During the three and nine months ended September 30, 2021, the Company recorded equity-based compensation expense related to LSUs of $1.6 million and $4.0 million, respectively, in general and administrative expenses on its Condensed Consolidated Statements of Operations.

Fair value assumptions. The aggregate grant date fair value of PSUs and LSUs was determined by a third-party valuation specialist using a Monte Carlo simulation model. The key valuation inputs were: (i) the forecast period, (ii) risk-free interest rate, (iii) implied equity volatility, (iv) stock price on the date of grant and, for PSUs, (v) correlation coefficient. The risk-free interest rates are the U.S. Treasury bond rates on the date of grant that correspond to each performance period. Implied equity volatility is derived by solving for an asset volatility and equity volatility based on the leverage of the Company and each of its peers. For the PSUs, the correlation coefficient measures the strength of the linear relationship between and amongst the Company and its peers based on historical stock price data.

The following table summarizes the assumptions used in the Monte Carlo simulation model to determine the grant date fair value and associated equity-based compensation expenses by grant date:

Grant date	January 18, 2021	February 11, 2021	April 13, 2021
Forecast period (years)	3 - 4	3 - 4	3 - 4
Risk-free interest rates	0.2% - 0.3%	0.2% - 0.3%	0.3% - 0.6%
Implied equity volatility	55% - 60%	55% - 60%	45% - 50%
Stock price on date of grant	$44.41	$49.66	$68.07

Restricted stock awards. The Company has granted restricted stock awards to its directors under the 2020 LTIP, which vest one-third annually over a three-year period subject to a service condition. The fair value of restricted stock awards is based on the closing price of the Company’s common stock on the date of grant or, if applicable, the date of modification. Compensation expense is recognized ratably over the requisite service period. During the three and nine months ended September 30, 2021, the Company recorded equity-based compensation expense for restricted stock awards of $0.3 million and $0.9 million, respectively, in general and administrative expenses on its Condensed Consolidated Statements of Operations.

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Class B Units in OMP GP

OMP GP previously granted restricted Class B Units to certain employees, including OMP’s named executive officers, as consideration for services to the Company. On March 30, 2021, in connection with the Midstream Simplification, certain Class B Units representing membership interests in OMP GP that were previously issued to certain of OMP’s named executive officers were converted into and exchanged for the right to receive restricted common units in OMP, subject to the following vesting schedule: (i) 34% vested on March 30, 2021, (ii) 33% will vest on March 30, 2022 and (iii) 33% will vest on March 30, 2023. As of September 30, 2021, the unamortized grant date fair value related to the unvested OMP restricted common units was $0.4 million and will be recognized over a remaining life of approximately two years.

Predecessor Equity-Based Compensation

The Predecessor previously granted equity-classified restricted stock awards and PSUs under its Amended and Restated 2010 Long Term Incentive Plan (the “Predecessor 2010 LTIP”). For the three and nine months ended September 30, 2020, the Predecessor recorded equity-based compensation expense of $3.1 million and $10.6 million, respectively, related to restricted stock awards and $1.6 million and $5.7 million, respectively, related to PSUs in general and administrative expenses on its Condensed Consolidated Statements of Operations. On the Emergence Date and pursuant to the Company’s restructuring plan, all outstanding unvested restricted stock awards and PSUs granted under the Predecessor 2010 LTIP vested, and there were no outstanding Predecessor restricted stock awards and PSUs at September 30, 2021 or December 31, 2020.

2020 Incentive Compensation Program. In the second quarter of 2020, the board of directors of the Predecessor implemented a revised 2020 incentive compensation program pursuant to which all 2020 equity-based awards previously granted were forfeited and concurrently replaced with cash retention incentives. In connection with the 2020 cash incentive compensation program, the Predecessor recorded $5.9 million and $12.4 million in general and administrative expenses on its Condensed Consolidated Statements of Operations for the three and nine months ended September 30, 2020, respectively.

15. Stockholders’ Equity

Dividends. On February 24, 2021, the Company declared a dividend of $0.375 per share of common stock. The dividend of $7.5 million was paid on March 22, 2021 to shareholders of record as of March 8, 2021.

On May 3, 2021, the Company declared a dividend of $0.375 per share of common stock. The dividend of $7.5 million was paid on May 31, 2021 to shareholders of record as of May 17, 2021.

On June 29, 2021, the Company declared a special dividend of $4.00 per share of common stock (the “Special Dividend”). The Special Dividend of $80.0 million was paid on July 21, 2021 to shareholders of record as of July 9, 2021.

On August 3, 2021, the Company declared a dividend of $0.375 per share of common stock. The dividend of $7.5 million was paid on August 27, 2021 to shareholders of record as of August 16, 2021.

On October 26, 2021, the Company declared a dividend of $0.50 per share of common stock payable on November 29, 2021 to shareholders of record as of November 15, 2021.

Future dividend payments will depend on the Company’s earnings, financial condition, capital requirements, level of indebtedness, statutory and contractual restrictions applicable to the payment of dividends and other considerations that the Board of Directors deems relevant.

Share repurchase program. In March 2021, the Board of Directors authorized a share-repurchase program covering up to $100.0 million of the Company’s common stock which expires on December 31, 2022. During the nine months ended September 30, 2021, the Company repurchased an aggregate amount of 190,783 shares of common stock at a weighted average price of $76.30 per common share for a total cost of $14.6 million.

There were no share repurchases made subsequent to September 30, 2021, except from October 28, 2021 through November 2, 2021, the Company repurchased 156,519 shares of common stock at a weighted average price of $121.22 per common share for a total cost of $19.0 million.

Warrants. As of September 30, 2021, there were 1,615,555 warrants outstanding. During the three and nine months ended September 30, 2021, there were 2,791 and 6,050 warrants exercised, respectively. The warrants, which are classified as equity, are exercisable to purchase one share of common stock per warrant at an initial exercise price of $94.57 per warrant. In connection with the Special Dividend, the exercise price decreased from $94.57 per warrant to $90.57 per warrant on July 12, 2021.

The warrants are exercisable from the date of issuance until November 19, 2024, at which time all unexercised warrants will expire and the rights of the holders of such warrants to purchase common stock will terminate. The number of shares of common stock for which a warrant is exercisable and the exercise price, are subject to adjustment from time to time upon the occurrence of certain events, including: (1) stock splits, reverse stock splits or stock dividends to holders of common stock or (2) a reclassification in respect of common stock.

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OMP Equity Offering. On June 29, 2021, OMP completed an underwritten public offering of 3,623,188 common units representing limited partnership interests at a price to the public of $24.00 per common unit (the “OMP Equity Offering”) and received net proceeds of $86.7 million, after deducting underwriting discounts, commissions and offering expenses. OMP used the proceeds from the OMP Equity Offering to redeem 3,623,188 common units held by Oasis for $87.0 million (the “OMP Unit Redemption”). Following the OMP Unit Redemption, the Company owns approximately 70%, and non-controlling interests own approximately 30% of OMP’s outstanding common units.

Tax benefits preservation plan. On August 3, 2021, the Board of Directors adopted a Tax Benefits Preservation Plan (the “Tax Plan”) designed to protect the availability of the Company’s Tax Benefits, which may be utilized in certain circumstances to reduce the Company’s future income tax obligations.

In adopting the Tax Plan, the Board of Directors declared a dividend of 1 preferred share purchase right (a “Right”) for each outstanding share of the Company’s common stock. The Rights will trade with the Company’s common stock and will expire at the close of business on the earlier of August 3, 2024 (three years from adoption) and the date upon which the Board of Directors determines that no Tax Benefits remain available or earlier, as described in more detail in the Tax Plan. The Rights will be exercisable if, among other things, a person or group of persons acquires 4.95% or more of the Company’s outstanding common stock.

16. Earnings (Loss) Per Share

Basic earnings (loss) per share is computed by dividing the earnings (loss) attributable to Oasis common stockholders by the weighted average number of shares outstanding for the periods presented. The calculation of diluted earnings (loss) per share includes the effect of potentially dilutive shares outstanding for the period using the treasury stock method, unless its effect is anti-dilutive. For the Successor period, potentially dilutive shares outstanding include unvested restricted stock awards, warrants and contingently issuable shares related to RSUs, PSUs and LSUs. For the Predecessor period, potentially dilutive shares outstanding included Predecessor unvested restricted stock awards, Predecessor contingently issuable shares related to PSUs and Predecessor senior convertible notes. There were no adjustments made to the income (loss) attributable to Oasis available to common stockholders in the calculation of diluted earnings (loss) per share during either the Successor period or Predecessor period.

The following table summarizes the basic and diluted weighted average common shares outstanding and the weighted average common shares excluded from the calculation of diluted weighted average common shares outstanding due to the anti-dilutive effect for the periods presented (in thousands):

	Successor	Predecessor	Successor	Predecessor
	Three Months Ended September 30, 2021	Three Months Ended September 30, 2020	Nine Months Ended September 30, 2021	Nine Months Ended September 30, 2020
Weighted average common shares outstanding:
Basic	19,812	318,287	19,905	317,365
Dilutive effect of equity-classified awards	956	—	603	—
Dilutive effect of warrants	18	—	—	—
Diluted	20,786	318,287	20,508	317,365
Anti-dilutive weighted average common shares:
Potential common shares	2,152	4,292	2,295	7,420

For the three and nine months ended September 30, 2021 (Successor), the diluted earnings per share calculation excludes the impact of unvested share based awards and outstanding warrants that were anti-dilutive under the treasury stock method. In addition, for the three and nine months ended September 30, 2020 (Predecessor), the Company incurred a net loss, and therefore the diluted loss per share calculation for those periods excludes the anti-dilutive effect of all potentially dilutive shares.

For the Predecessor period, the conversion value of the Predecessor senior convertible notes did not exceed the principal amount; accordingly, there was no impact to diluted earnings per share.

17. Business Segment Information

The Company has 2 reportable segments: E&P and midstream. The Company’s E&P business segment is engaged in the acquisition and development of oil and gas properties. Revenues for the E&P business segment are primarily derived from the sale of crude oil and natural gas production.

The Company’s midstream business segment performs midstream services including: (i) natural gas gathering, compression,

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processing and gas lift supply; (ii) crude oil gathering, terminaling and transportation; (iii) produced and flowback water gathering and disposal; and (iv) freshwater supply and distribution. Revenues for the midstream segment are derived from performing these services for the Company’s E&P segment as well as third-party producers. The revenues and expenses related to services provided by the midstream segment for the Company’s ownership interests are eliminated in consolidation, and only the revenues and expenses related to non-affiliated interest owners and third-party customers are included in the Company’s Condensed Consolidated Statements of Operations.

The Company’s corporate activities have been allocated to the supported business segments accordingly. Management evaluates the performance of the Company’s business segments based on operating income (loss), which is defined as segment operating revenues less operating expenses, including depreciation, depletion and amortization.

The following table summarizes financial information for the Company’s 2 business segments for the periods presented:

	E&P		Midstream		Eliminations		Consolidated
	(In thousands)
Successor
Three months ended September 30, 2021:
Revenues from non-affiliates	$	335,327	$	66,712	$	—	$	402,039
Inter-segment revenues	—		41,561		(41,561)		—
Total revenues	335,327		108,273		(41,561)		402,039
Operating income	153,125		51,289		(824)		203,590
Total other expense, net	(109,085)		(11,173)		—		(120,258)
Income before income taxes	$	44,040	$	40,116	$	(824)	$	83,332
Lease operating expenses	$	44,914	$	—	$	(15,607)	$	29,307
Gathering, processing and transportation expenses	30,028		—		(13,628)		16,400
General and administrative expenses(1)	15,702		6,668		(2,856)		19,514
Equity-based compensation expenses	4,144		143		—		4,287
Predecessor
Three months ended September 30, 2020:
Revenues from non-affiliates	$	215,636	$	55,423	$	—	$	271,059
Inter-segment revenues	—		54,638		(54,638)		—
Total revenues	215,636		110,061		(54,638)		271,059
Operating income (loss)	(8,603)		48,132		(1,005)		38,524
Total other expense, net	(87,953)		(2,812)		—		(90,765)
Income (loss) before income taxes	$	(96,556)	$	45,320	$	(1,005)	$	(52,241)
Lease operating expenses	$	41,235	$	—	$	(11,882)	$	29,353
Gathering, processing and transportation expenses	32,003		—		(11,675)		20,328
General and administrative expenses(1)	44,088		9,089		(3,926)		49,251
Equity-based compensation expenses	4,502		400		(68)		4,834
Successor
Nine months ended September 30, 2021:

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Revenues from non-affiliates	$	947,013	$	203,545	$	—	$	1,150,558
Inter-segment revenues	—		125,007		(125,007)		—
Total revenues	947,013		328,552		(125,007)		1,150,558
Operating income (loss)	593,493		139,946		(3,441)		729,998
Total other income (expense), net	(574,583)		(26,039)		—		(600,622)
Income before income taxes	$	18,910	$	113,907	$	(3,441)	$	129,376
Lease operating expenses	$	146,414	$	—	$	(47,526)	$	98,888
Gathering, processing and transportation expenses	90,920		—		(38,324)		52,596
General and administrative expenses(1)	47,084		23,403		(10,026)		60,461
Equity-based compensation expenses	10,518		669		—		11,187
Predecessor
Nine months ended September 30, 2020:
Revenues from non-affiliates	$	668,849	$	156,360	$	—	$	825,209
Inter-segment revenues	—		160,377		(160,377)		—
Total revenues	668,849		316,737		(160,377)		825,209
Operating income (loss)	(4,866,759)		36,526		(4,995)		(4,835,228)
Total other income (expense), net	140,580		(38,568)		—		102,012
Loss before income taxes	$	(4,726,179)	$	(2,042)	$	(4,995)	$	(4,733,216)
Lease operating expenses	$	144,912	$	—	$	(36,182)	$	108,730
Gathering, processing and transportation expenses	105,897		—		(32,340)		73,557
General and administrative expenses(1)	103,051		26,995		(12,178)		117,868
Equity-based compensation expenses	15,909		1,031		(409)		16,531
Successor
At September 30, 2021:
Property, plant and equipment, net	$	692,271	$	893,333	$	(2,760)	$	1,582,844
Total assets	1,939,695		1,062,577		(2,760)		2,999,512
At December 31, 2020:
Property, plant and equipment, net	$	837,020	$	892,043	$	(276)	$	1,728,787
Total assets	1,093,253		1,066,060		(276)		2,159,037

___________________

(1)Includes equity-based compensation expenses.

18. Commitments and Contingencies

As of September 30, 2021, the Company’s material off-balance sheet arrangements and transactions include $6.7 million in outstanding letters of credit under its revolving credit facilities and $10.2 million in net surety bond exposure issued as financial assurance on certain agreements.

As of September 30, 2021, there have been no material changes to the Company’s commitments and contingencies disclosed in Note 24 — Commitments and Contingencies in the Company’s 2020 Annual Report other than the items discussed below.

Volume commitment agreements. As of December 31, 2020, the Company had $32.6 million of estimable future commitments pursuant to volume commitment agreements related to properties divested in the Primary Permian Basin Sale. Such volume commitment agreements were assigned to Percussion at closing, and the Company no longer has any remaining volume commitments associated with these agreements. In addition, the Company previously disclosed in its 2020 Annual Report potential future obligations associated with a continuous development agreement (the “CDA”) concerning certain drilling and development obligations in the Permian Basin. The CDA was assigned to Percussion upon closing of the Primary Permian Basin Sale, and the Company does not have any future obligations associated with this agreement.

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In August 2021, certain escalations became effective pursuant to an agreement to transport a minimum quantity of crude oil volumes in the Williston Basin. As of September 30, 2021, the Company’s estimable future commitment under this agreement was $258.6 million and has a remaining term of approximately 7 years.

Litigation. The Company is party to various legal and/or regulatory proceedings from time to time arising in the ordinary course of business. When the Company determines that a loss is probable of occurring and is reasonably estimable, the Company accrues an undiscounted liability for such contingencies based on its best estimate using information available at the time. The Company discloses contingencies where an adverse outcome may be material, or in the judgment of management, the matter should otherwise be disclosed.

Mandan, Hidatsa and Arikara Nation (“MHA Nation”) Title Dispute. This matter relates to certain leases acquired by the Company from QEP in October 2021: in June 2018, the MHA Nation notified QEP of its position that QEP has no valid lease covering certain minerals underlying the Missouri and Little Missouri Riverbeds on the Fort Berthold Reservation in North Dakota. The MHA Nation also passed a resolution purporting to rescind those portions of QEP's IMDA lease covering the disputed minerals underlying the Missouri River. QEP responded in September 2018 stating that the minerals underlying the Missouri River are properly leased. In May 2020, the Office of the Solicitor of the United States Department of the Interior (the “Department of the Interior”) issued an opinion (the “Missouri River Opinion”) finding that the State of North Dakota, not the MHA nation, is the legal owner of the minerals underlying the Missouri River. The MHA Nation filed actions in two federal courts seeking to overturn the May 2020 decision, and in March 2021, the Department of the Interior withdrew the Missouri River Opinion.

Mirada litigation. As previously disclosed in the Company’s 2020 Annual Report, the Company entered into a Settlement and Mutual Release Agreement (the “Mirada Settlement Agreement”) with Mirada Energy, LLC and certain related parties (“Mirada”) on September 28, 2020. The Mirada Settlement Agreement provides for, among other things, payment by OPNA to Mirada of $42.8 million. The Company paid Mirada $20.0 million on the Emergence Date and $22.8 million in May 2021. These amounts were previously accrued for in the Company’s condensed consolidated financial statements, and there are no remaining settlement payments outstanding as of September 30, 2021.

19. Subsequent Events

On October 26, 2021, the Company announced that on October 25, 2021, OMP and OMP GP entered into an Agreement and Plan of Merger (the “Merger Agreement”), with Crestwood Equity Partners LP, a Delaware limited partnership (“Crestwood”), Project Falcon Merger Sub LLC, a Delaware limited liability company and direct wholly-owned subsidiary of Crestwood (“Merger Sub”), Project Phantom Merger Sub LLC, a Delaware limited liability company and direct wholly-owned subsidiary of Crestwood (“GP Merger Sub”), and, solely for the purposes of Section 2.1(a)(i) of the Merger Agreement, Crestwood Equity GP LLC, a Delaware limited liability company and the general partner of Crestwood (“Crestwood GP”). Upon the terms and subject to the conditions set forth in the Merger Agreement, Merger Sub will merge with and into OMP (the “LP Merger”), with OMP surviving the LP Merger as a subsidiary of Crestwood, and GP Merger Sub will merge with and into OMP GP (the “GP Merger” and, together with the LP Merger, the “Mergers”), with OMP GP surviving the GP Merger as a wholly-owned subsidiary of Crestwood.

Under the terms of the Merger Agreement, Oasis, as a unitholder of OMP, will receive $160.0 million in cash in addition to approximately 21.0 million common units of Crestwood in aggregate in exchange for its ownership of OMP common units and non-economic general partner stake in OMP GP. At the effective time of the Mergers (the “Effective Time”): (i) 6,520,944 common units representing limited partner interests in OMP (“OMP Common Units”) issued and outstanding immediately prior to the Effective Time and owned by OMS Holdings (such OMP Common Units, the “Sponsor Cash Units”), will be converted into and will thereafter represent the right to receive $150.0 million in cash in the aggregate and each other OMP Common Unit issued and outstanding immediately prior to the Effective Time owned by the Company or its subsidiaries (other than OMP) (together with the Sponsor Cash Units, the “Sponsor Units”) will be converted into and will thereafter represent the right to receive 0.7680 common units representing limited partner interests in Crestwood (“Crestwood Common Units”); (ii) each OMP Common Unit issued and outstanding immediately prior to the Effective Time (other than the Sponsor Units) will be converted into and will thereafter represent the right to receive 0.8700 (the “Public Holder Exchange Ratio”) Crestwood Common Units and (iii) all of the limited liability company interests of OMP GP issued and outstanding as of immediately prior to the Effective Time will be converted into and will thereafter represent the right to receive $10.0 million in cash. Upon completion of the Mergers, the Company is expected to own approximately 22% of the Crestwood Common Units.

The Mergers were unanimously approved by the Board of Directors of both Oasis and Crestwood and have also been unanimously approved by the Board of Directors and Conflicts Committee of OMP GP. The Mergers are expected to close in the first quarter of 2022 and are subject to customary closing conditions.

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Contemporaneously with the execution of the Merger Agreement, the Company, OMP, Crestwood, OMP GP and OMS Holdings entered into a support agreement (the “Support Agreement”) regarding the OMP Common Units owned by the Company and OMS Holdings (or their affiliates). Pursuant to the Support Agreement, the Company and OMS Holdings have agreed to, among other things (and as applicable), following effectiveness of a registration statement of Crestwood on Form S-4 in connection with the issuance of Crestwood Common Units in the LP Merger, execute and deliver, or cause an affiliate to execute and deliver, a written consent covering all of their OMP Units, approving the Merger Agreement and the transactions contemplated thereby. The Support Agreement and the Merger Agreement may be terminated in the event the written consent is not delivered.

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

The following discussion and analysis of our financial condition and results of operations should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” contained in our Annual Report on Form 10-K for the year ended December 31, 2020 (“2020 Annual Report”), as well as the unaudited condensed consolidated financial statements and notes thereto included in this Quarterly Report on Form 10-Q.

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). These forward-looking statements are subject to a number of risks and uncertainties, many of which are beyond our control. All statements, other than statements of historical fact included in this Quarterly Report on Form 10-Q, regarding our strategic tactics, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this Quarterly Report on Form 10-Q, the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “may,” “continue,” “predict,” “potential,” “project” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Our forward-looking statements address the various risks and uncertainties associated with the extraordinary market environment and impacts resulting from the novel coronavirus 2019 (“COVID-19”) pandemic and the related impacts to energy demand, our businesses, operations, earnings and results. In particular, the factors discussed below and detailed under “Part II, Item 1A. Risk Factors” in this Quarterly Report on Form 10-Q could affect our actual results and cause our actual results to differ materially from expectations, estimates, or assumptions expressed in, forecasted in, or implied in such forward-looking statements.

Forward-looking statements may include statements about:

•crude oil, natural gas and natural gas liquids (“NGL”) realized prices;

•developments in the global economy as well as the public health crisis related to the COVID-19 pandemic and resulting demand and supply for crude oil and natural gas;

•uncertainty regarding the worldwide response to COVID-19, including the impact of new virus strains, the administration of vaccines and the risks associated with restrictions on various commercial and economic activities; such restrictions are designed to protect public health but also have the effect of significantly reducing demand for crude oil and natural gas;

•uncertainty regarding the future actions of foreign oil producers and the related impacts such actions have on the balance between the supply of and demand for crude oil and natural gas;

•uncertainty regarding the timing, pace and extent of an economic recovery in the U.S. and elsewhere, which in turn will likely affect demand for crude oil and natural gas;

•levels of crude oil and natural gas inventory stored in the U.S. and elsewhere;

•general economic conditions;

•inflation rates;

•our business strategy;

•estimated future net reserves and present value thereof;

•timing and amount of future production of crude oil and natural gas;

•drilling and completion of wells;

•estimated inventory of wells remaining to be drilled and completed;

•costs of exploiting and developing our properties and conducting other operations;

•availability of drilling, completion and production equipment and materials;

•availability of qualified personnel;

•owning and operating a midstream company, including ownership interests in a master limited partnership;

•infrastructure for produced and flowback water gathering and disposal;

•gathering, transportation and marketing of crude oil and natural gas in the Williston Basin and other regions in the U.S.;

•property acquisitions and divestitures;

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•integration and benefits of property acquisitions or the effects of such acquisitions on our cash position and levels of indebtedness;

•the recently announced merger of Oasis Midstream Partners LP (“OMP”) and Crestwood Equity Partners LP (“Crestwood”), including risks that the proposed transaction may not be consummated or the benefits contemplated therefrom may not be realized, the ability to obtain requisite regulatory and unitholder approval and the satisfaction of the other conditions to the consummation of the proposed transaction, the ability of Crestwood to successfully integrate OMP’s operations and employees and realize anticipated synergies and cost savings and the potential impact of the announcement or consummation of the proposed transaction on relationships, including with employees, suppliers, customers, competitors and credit rating agencies;

•the amount, nature and timing of capital expenditures;

•availability and terms of capital;

•our financial strategic tactics, budget, projections, execution of business plan and operating results;

•cash flows and liquidity;

•our ability to return capital to shareholders;

•our ability to utilize net operating loss carryforwards or other tax attributes in future periods;

•our ability to comply with the covenants under our credit agreements and other indebtedness;

•operating hazards, natural disasters, weather-related delays, casualty losses and other matters beyond our control;

•interruptions in service and fluctuations in tariff provisions of third-party connecting pipelines;

•potential effects arising from cyber threats, terrorist attacks and any consequential or other hostilities;

•changes in environmental, safety and other laws and regulations;

•execution of our environmental, social and governance (“ESG”) initiatives;

•effectiveness of risk management activities;

•competition in the oil and gas industry;

•counterparty credit risk;

•environmental liabilities;

•governmental regulation and the taxation of the oil and gas industry;

•developments in crude oil-producing and natural gas-producing countries;

•technology;

•the effects of accounting pronouncements issued periodically during the periods covered by forward-looking statements;

•uncertainty regarding future operating results;

•our ability to successfully forecast future operating results and manage activity levels with ongoing macroeconomic uncertainty;

•plans, objectives, expectations and intentions contained in this report that are not historical; and

•certain factors discussed elsewhere in this Quarterly Report on Form 10-Q, in our 2020 Annual Report and in our other filings with the U.S Securities and Exchange Commission (the “SEC”).

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All forward-looking statements speak only as of the date of this Quarterly Report on Form 10-Q. We disclaim any obligation to update or revise these statements unless required by securities law, and you should not place undue reliance on these forward-looking statements. Although we believe that our plans, intentions and expectations reflected in or suggested by the forward-looking statements we make in this Quarterly Report on Form 10-Q are reasonable, we can give no assurance that these plans, intentions or expectations will be achieved. Some of the key factors which could cause actual results to vary from our expectations include changes in crude oil and natural gas prices, weather and environmental conditions, the timing of planned capital expenditures, availability of acquisitions, the ability to realize the anticipated benefits from the Williston Basin Acquisition or OMP Merger (each as defined herein), uncertainties in estimating proved reserves and forecasting production results, operational factors affecting the commencement or maintenance of producing wells, the condition of the capital markets generally, as well as our ability to access them, inflation, the proximity to and capacity of transportation facilities, and uncertainties regarding environmental regulations or litigation and other legal or regulatory developments affecting our business, as well as those factors discussed below and elsewhere in this Quarterly Report on Form 10-Q, all of which are difficult to predict. In light of these risks, uncertainties and assumptions, the forward-looking events discussed may not occur. These cautionary statements qualify all forward-looking statements attributable to us or persons acting on our behalf.

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Overview

We are an independent exploration and production (“E&P”) company focused on the acquisition and development of onshore, unconventional crude oil and natural gas resources in the United States. Oasis Petroleum North America LLC conducts our E&P activities and owns our oil and gas properties located in the North Dakota and Montana regions of the Williston Basin. During the second quarter of 2021, we sold our E&P assets in the Texas region of the Permian Basin. In addition to our E&P segment, we operate a midstream business through OMP, a leading gathering and processing master limited partnership that owns, develops, operates and acquires a diversified portfolio of midstream assets in North America. We own OMP GP LLC, a Delaware limited liability company and the general partner of OMP (“OMP GP”), and approximately 70% of OMP. We derive significant cash flows from the midstream segment through distributions from our ownership of OMP limited partner units.

Recent Developments

Williston Basin Acquisition

On October 21, 2021, we completed our acquisition of approximately 95,000 net acres in the Williston Basin, effective April 1, 2021, from QEP Energy Company, a wholly-owned subsidiary of Diamondback Energy, Inc. for an adjusted purchase price of $585.8 million (the “Williston Basin Acquisition”). The adjusted purchase price included a deposit of $74.5 million paid on May 3, 2021 and $511.3 million paid at closing on October 21, 2021. We funded the Williston Basin Acquisition with cash on hand, which included proceeds from the Permian Basin Sale (defined below) and our issuance of $400.0 million in aggregate principal amount of 6.375% senior unsecured notes due 2026 (the “Oasis Senior Notes”).

Permian Basin Sale

On June 29, 2021, we completed the sale of our remaining upstream assets in the Texas region of the Permian Basin, effective March 1, 2021, to Percussion Petroleum Operating II, LLC (“Percussion”) for an aggregate purchase price of $450.0 million (the “Primary Permian Basin Sale”). The purchase price consisted of $375.0 million cash at closing and up to three earn-out payments of $25.0 million per year for each of 2023, 2024 and 2025 if the average daily settlement price of NYMEX West Texas Intermediate (“NYMEX WTI”) crude oil exceeds $60 per barrel for such year (the “Permian Basin Sale Contingent Consideration”). We received cash proceeds of $347.3 million, consisting of a deposit of $31.9 million on May 20, 2021 and $315.4 million at closing on June 29, 2021. The total consideration remains subject to earn-out payments and customary post-closing adjustments.

In addition to the Primary Permian Basin Sale, we also divested certain wellbore interests in the Texas region of the Permian Basin to separate buyers in the second quarter of 2021 (the “Additional Permian Basin Sale” and together with the Primary Permian Basin Sale, the “Permian Basin Sale”). We received cash proceeds from the Additional Permian Basin Sale of $24.0 million, and we expect to receive total aggregate cash proceeds of $30.0 million.

Change in Chief Executive Officer

On April 13, 2021, Daniel E. Brown was appointed Chief Executive Officer of the Company. At the same time, Mr. Brown was also appointed to the Company’s Board of Directors. Mr. Brown replaced Douglas E. Brooks, who was previously appointed to serve as Chief Executive Officer on an interim basis. Mr. Brooks continues to serve in his role as Board Chair.

Dakota Access Pipeline

The U.S. Army Corps of Engineers (the “Corps”) is currently conducting a court-ordered environmental review to determine whether the Dakota Access Pipeline (“DAPL”) poses a threat to the drinking water supply of the Standing Rock Sioux Reservation. Once this review is finished, which completion is estimated by the Corps to occur by no later than March 2022, the Corps will determine whether DAPL is safe to operate or must be permanently shut down. On April 9, 2021, the Biden Administration announced that the Corps will not take immediate action to shut down DAPL while it conducts the environmental review, and on May 3, 2021, the Corps filed a Status Report with the federal district court, confirming that it currently is not seeking a shutdown of DAPL while the agency conducts the environmental review. In a related legal proceeding involving the Standing Rock Sioux Tribe’s request for an injunction to shut down DAPL while the environmental review is being conducted, U.S. District Judge James Boasberg ruled on May 21, 2021 that DAPL will not be forced to shut down while the Corps conducts the environmental review, indicating that the tribe had failed to make a successful showing of irreparable harm based on the threat of an oil spill. The pipeline currently remains in operation while the Corps conducts its review.

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Midstream Transactions

Midstream Simplification

On March 30, 2021, we closed on the transactions contemplated by a contribution and simplification agreement pursuant to which we contributed our remaining 64.7% interest in Bobcat DevCo LLC (“Bobcat DevCo”) and remaining 30.0% interest in Beartooth DevCo LLC (“Beartooth DevCo”) to OMP as well as eliminated OMP’s incentive distribution rights for total consideration of approximately $512.5 million, including cash consideration of $231.5 million and 14.8 million OMP common units (the “Midstream Simplification”). The effective date for the Midstream Simplification was January 1, 2021. See “Item 1. — Financial Statements (Unaudited)—Note 2—Summary of Significant Accounting Policies—Basis of Presentation” for more information.

OMP Unit Redemption

On June 29, 2021, OMP completed an underwritten public offering of 3,623,188 common units representing limited partnership interests at a price to the public of $24.00 per common unit (the “OMP Equity Offering”) and received net proceeds of $86.7 million, after deducting underwriting discounts, commissions and offering expenses. OMP used the proceeds from the OMP Equity Offering to redeem an equal number of common units held by Oasis (the “OMP Unit Redemption”) for $87.0 million. Following the OMP Unit Redemption, we own approximately 70% of OMP’s outstanding common units.

OMP Merger

On October 25, 2021, the Company, OMP and OMP GP entered into an Agreement and Plan of Merger (the “Merger Agreement”), with Crestwood, Project Falcon Merger Sub LLC, a Delaware limited liability company and direct wholly-owned subsidiary of Crestwood (“Merger Sub”), Project Phantom Merger Sub LLC, a Delaware limited liability company and direct wholly-owned subsidiary of Crestwood (“GP Merger Sub”), and, solely for the purposes of Section 2.1(a)(i) of the Merger Agreement, Crestwood Equity GP LLC, a Delaware limited liability company and the general partner of Crestwood (“Crestwood GP”). Upon the terms and subject to the conditions set forth in the Merger Agreement, Merger Sub will merge with and into OMP (the “LP Merger”), with OMP surviving the LP Merger as a subsidiary of Crestwood, and GP Merger Sub will merge with and into OMP GP (the “GP Merger” and, together with the LP Merger, the “Mergers”), with OMP GP surviving the GP Merger as a wholly-owned subsidiary of Crestwood.

Under the terms of the Merger Agreement, Oasis, as a unitholder of OMP, will receive $160.0 million in cash in addition to approximately 21.0 million common units of Crestwood in aggregate in exchange for its ownership of OMP common units and non-economic general partner stake in OMP GP. At the effective time of the Mergers (the “Effective Time”): (i) 6,520,944 common units representing limited partner interests in OMP (“OMP Common Units”) issued and outstanding immediately prior to the Effective Time and owned by OMS Holdings LLC, a Delaware limited liability company (“OMS Holdings”) and subsidiary of the Company (such OMP Common Units, the “Sponsor Cash Units”), will be converted into and will thereafter represent the right to receive $150.0 million in cash in the aggregate and each other OMP Common Unit issued and outstanding immediately prior to the Effective Time owned by the Company or its subsidiaries (other than OMP) (together with the Sponsor Cash Units, the “Sponsor Units”) will be converted into and will thereafter represent the right to receive 0.7680 common units representing limited partner interests in Crestwood (“Crestwood Common Units”); (ii) each OMP Common Unit issued and outstanding immediately prior to the Effective Time (other than the Sponsor Units) will be converted into and will thereafter represent the right to receive 0.8700 (the “Public Holder Exchange Ratio”) Crestwood Common Units and (iii) all of the limited liability company interests of OMP GP issued and outstanding as of immediately prior to the Effective Time will be converted into and will thereafter represent the right to receive $10.0 million in cash. Upon completion of the Mergers, the Company is expected to own approximately 22% of the Crestwood Common Units.

The Mergers were unanimously approved by the Board of Directors of both Oasis and Crestwood and have also been unanimously approved by the Board of Directors and Conflicts Committee of OMP GP. We expect the Mergers will be completed in the first quarter of 2022, subject to customary closing conditions.

Contemporaneously with the execution of the Merger Agreement, the Company, OMP, Crestwood, OMP GP and OMS Holdings entered into a support agreement (the “Support Agreement”) regarding the OMP Common Units owned by the Company and OMS Holdings (or their affiliates). Pursuant to the Support Agreement, the Company and OMS Holdings have agreed to, among other things (and as applicable), following effectiveness of a registration statement of Crestwood on Form S-4 in connection with the issuance of Crestwood Common Units in the LP Merger, execute and deliver, or cause an affiliate to execute and deliver, a written consent covering all of their OMP Units, approving the Merger Agreement and the transactions contemplated thereby. The Support Agreement and the Merger Agreement may be terminated in the event the written consent is not delivered.

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Market Conditions and COVID-19

COVID-19 remains a global health crisis and there continues to be considerable uncertainty regarding the extent to which COVID-19 and its variants will continue to spread. Public health and governmental authorities have commenced programs to administer vaccines and certain restrictions imposed to contain the spread of COVID-19 have been lifted. In September 2021, President Biden announced a COVID-19 action plan that would have the Occupational Safety and Health Administration develop an Emergency Temporary Standard which may include new obligations for employers with one hundred or more employees with respect to vaccinations, testing and paid time off. We monitor mandates related to COVID-19 at both the federal and state levels on an ongoing basis and continue to assess the potential impacts of those mandates. Despite improvements in global economic activity levels and higher energy demand compared to 2020, the impacts of COVID-19 continue to be unpredictable, including the impacts of new virus strains, the risk of renewed restrictions and the uncertainty of successful administration of effective treatments and vaccines. We are unable to reasonably estimate the period of time that related conditions could exist or the extent to which they could impact our business, results of operations, financial condition or cash flows. Commodity prices have improved from historic lows in 2020, however, further negative impacts from COVID-19 may require us to adjust our business plan. In response to the impacts of COVID-19 and the economic environment, we reduced our workforce during the first quarter of 2021 to adjust our business to expected lower levels of activity and operate in a sustainable and cost-efficient manner.

We are focused on the safety of our employees, contractors, and the communities where we work as we continue to operate during the COVID-19 pandemic. We have deployed additional safety protocols and training procedures, including enhanced daily cleaning in common spaces, use of face coverings, limiting use of conference rooms and group gatherings and adherence to social distancing requirements. Our Crisis Management Team continues to monitor public health data and guidance, engages with peer companies, and participates with industry associations to ensure alignment with guidance for employee health and safety.

Commodity Prices

Our revenue, profitability and ability to return cash to shareholders depend substantially on factors beyond our control, such as economic, political and regulatory developments as well as competition from other sources of energy. Prices for crude oil, natural gas and NGLs have experienced significant fluctuations in recent years and may continue to fluctuate widely in the future. In an effort to improve price realizations from the sale of our crude oil, natural gas and NGLs, we manage our commodities marketing activities in-house, which enables us to market and sell our crude oil, natural gas and NGLs to a broader array of potential purchasers. We enter into crude oil, natural gas and NGL sales contracts with purchasers who have access to transportation capacity, utilize derivative financial instruments to manage our commodity price risk and enter into physical delivery contracts to manage our price differentials. During the third quarter of 2021, our crude oil price differentials averaged $0.43 per barrel discount to NYMEX WTI. Due to the availability of other markets and pipeline connections, we do not believe that the loss of any single crude oil or natural gas customer would have a material adverse effect on our results of operations or cash flows.

Additionally, we sell a significant amount of our crude oil production through gathering systems connected to multiple pipeline and rail facilities. These gathering systems, which originate at the wellhead, reduce the need to transport barrels by truck from the wellhead, helping remove trucks from local highways and reduce greenhouse gas emissions. As of September 30, 2021, 93% of our gross operated crude oil production and substantially all of our gross operated natural gas production were connected to gathering systems.

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Recent Highlights:

•Declared a dividend for third quarter of 2021 of $0.50 per share of common stock. The dividend will be payable on November 29, 2021 to shareholders of record as of November 15, 2021.

•Production volumes averaged 51,804 barrels of oil equivalent per day (“Boepd”) (62% oil) in the third quarter of 2021.

•E&P capital expenditures were $41.9 million in the third quarter of 2021.

•E&P lease operating expense (“LOE”) was $9.42 per barrel of oil equivalent (“Boe”) in the third quarter of 2021.

•Crude oil differentials averaged $0.43 to NYMEX WTI in the third quarter of 2021.

•Net cash provided by operating activities was $294.4 million for the three months ended September 30, 2021. Adjusted EBITDA attributable to Oasis, a non-GAAP financial measure, was $116.2 million for the three months ended September 30, 2021. See “Non-GAAP Financial Measures” below.

Results of Operations

Comparability

Upon our emergence from bankruptcy on November 19, 2020 (the “Emergence Date”), we adopted fresh start accounting, which resulted in us becoming a new entity for financial reporting purposes. Accordingly, the condensed consolidated financial statements on or after the Emergence Date are not comparable to the condensed consolidated financial statements prior to the Emergence Date. References to “Successor” relate to our financial position and results of operations as of and subsequent to the Emergence Date. References to “Predecessor” relate to our financial position prior to, and our results of operations through and including, the Emergence Date. Upon adoption of fresh start accounting, our assets and liabilities were recorded at their estimated fair values as of the Emergence Date. As a result, the impact to the comparability of the Predecessor and Successor results is generally limited to those areas associated with the basis in and accounting for our oil and gas and other properties.

Revenues

Our crude oil and natural gas revenues are derived from the sale of crude oil and natural gas production. These revenues do not include the effects of derivative instruments and may vary significantly from period to period as a result of changes in volumes of production sold or changes in commodity prices. Our purchased oil and gas sales are primarily derived from the sale of crude oil and natural gas purchased through our marketing activities primarily to optimize transportation costs, for blending at our crude oil terminal or to cover production shortfalls. Revenues and expenses from crude oil and natural gas sales and purchases are generally recorded on a gross basis, as we act as a principal in these transactions by assuming control of the purchased crude oil or natural gas before it is transferred to the customer. In certain cases, we enter into sales and purchases with the same counterparty in contemplation of one another, and these transactions are recorded on a net basis.

Our midstream revenues are primarily derived from natural gas gathering, compression, processing and gas lift supply; sales of residue gas and NGLs related to third-party natural gas purchase arrangements; produced and flowback water gathering and disposal; crude oil gathering, terminaling and transportation and fresh water distribution. Our other services revenues are derived from equipment rentals, and also include revenues from well completion services prior to our exit from the well services business in the first quarter of 2020 (the “Well Services Exit”).

A significant portion of our midstream revenues and all of our other services revenues are from services performed for our operated wells. Intercompany revenues for work performed for our ownership interests are eliminated in consolidation, and only the revenues related to non-affiliated interest owners and other third-party customers are included in midstream and other services revenues.

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The following table summarizes our revenues, production data and sales prices for the periods presented:

	Successor						Predecessor
	Three Months Ended September 30, 2021		Three Months Ended June 30, 2021		Nine Months Ended September 30, 2021			Nine Months Ended September 30, 2020
Revenues (in thousands)
Crude oil revenues	$	205,731	$	206,729	$	598,278		$	448,904
Natural gas revenues	75,905		48,498		184,046			63,631
Purchased oil and gas sales	53,570		81,855		183,885			167,824
Midstream revenues	66,712		55,783		183,807			138,164
Other services revenues	121		195		542			6,686
Total revenues	$	402,039	$	393,060	$	1,150,558		$	825,209
Production data
Crude oil (MBbls)	2,934		3,155		9,402			12,263
Natural gas (MMcf)	10,989		10,703		32,707			35,881
Oil equivalents (MBoe)	4,766		4,939		14,853			18,243
Average daily production (Boepd)	51,804		54,271		54,407			66,581
Average sales prices
Crude oil (per Bbl)
Average sales price	$	70.12	$	65.52	$	63.63		$	36.61
Effect of derivative settlements(1)	(26.31)		(17.75)		(16.62)			13.17
Average realized price after the effect of derivative settlements(1)	$	43.81	$	47.77	$	47.01		$	49.78
Natural gas (per Mcf)(2)
Average sales price	$	6.91	$	4.53	$	5.63		$	1.77
Effect of derivative settlements(1)	(0.39)		—		(0.12)			—
Average realized price after the effect of derivative settlements(1)	$	6.52	$	4.53	$	5.51		$	1.77

____________________

(1)The effect of derivative settlements includes the cash received or paid for the gains or losses on commodity derivatives settled in the periods presented. Our commodity derivatives do not qualify for or were not designated as hedging instruments for accounting purposes.

(2)Natural gas prices include the value for natural gas and NGLs.

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Three months ended September 30, 2021 as compared to three months ended June 30, 2021

Crude oil and natural gas revenues. Our crude oil and natural gas revenues increased $26.4 million to $281.6 million during the three months ended September 30, 2021. This increase was primarily driven by a $14.5 million increase due to higher crude oil realized prices and a $25.4 million increase due to higher natural gas realized prices, offset by a $13.5 million decrease driven by lower crude oil and natural gas production volumes sold quarter over quarter. Average crude oil sales prices, without derivative settlements, increased by $4.60 per barrel quarter over quarter to an average of $70.12 per barrel for the three months ended September 30, 2021. Average natural gas sales prices, which include the value for residue gas and NGLs and do not include derivative settlements, increased by $2.38 per Mcf quarter over quarter to an average of $6.91 per Mcf for the three months ended September 30, 2021. Average daily production volumes sold decreased by 2,467 Boepd to 51,804 Boepd quarter over quarter primarily driven by a decrease in crude oil production as a result of the Permian Basin Sale in the second quarter of 2021.

Purchased oil and gas sales. Purchased oil and gas sales, which consist primarily of the sale of crude oil purchased to optimize transportation costs, for blending at our crude oil terminal or to cover production shortfalls, decreased $28.3 million to $53.6 million for the three months ended September 30, 2021. This decrease was primarily due to a reduction in crude oil volumes purchased and then subsequently sold in the Williston Basin.

Midstream revenues. Midstream revenues increased $10.9 million to $66.7 million during the three months ended September 30, 2021. This increase was primarily driven by a $7.0 million increase in natural gas revenues due to an increase in sales from natural gas purchase arrangements, coupled with a $2.9 million increase in produced and flowback water revenues and a $1.4 million increase in crude oil revenues.

Nine months ended September 30, 2021 as compared to nine months ended September 30, 2020

Crude oil and natural gas revenues. Our crude oil and natural gas revenues increased $269.8 million to $782.3 million during the nine months ended September 30, 2021. This increase was primarily driven by a $469.7 million increase due to higher crude oil and natural gas realized prices, offset by a $199.9 million decrease due to the lower crude oil and natural gas production volumes sold period over period. Average crude oil sales prices, without derivative settlements, increased by $27.02 per barrel to an average of $63.63 per barrel, and average natural gas sales prices, which include the value for residue gas and NGLs and do not include derivative settlements, increased by $3.86 per Mcf to an average of $5.63 per Mcf for the nine months ended September 30, 2021. Average daily production sold decreased by 12,174 Boepd to 54,407 Boepd period over period. The decrease in average daily production volumes sold period over period was due to a reduction in new wells coming online as a result of fewer well completions, coupled with the Permian Basin Sale in the second quarter of 2021.

Purchased oil and gas sales. Purchased oil and gas sales increased $16.1 million to $183.9 million for the nine months ended September 30, 2021. This increase was primarily due to higher crude oil sales prices period over period, partially offset by lower crude oil volumes purchased and then subsequently sold in the Williston Basin and Permian Basin.

Midstream revenues. Midstream revenues were $183.8 million for the nine months ended September 30, 2021, which was a $45.7 million increase period over period. This increase was driven by a $50.2 million increase in natural gas revenues due to an increase in sales from natural gas purchase arrangements due to higher residue gas and NGL prices. This was offset by a $2.6 million decrease in produced and flowback water revenues and a $1.2 million decrease in freshwater revenues.

Other services revenues. Other services revenues decreased by $6.2 million to $0.5 million for the nine months ended September 30, 2021 as compared to the nine months ended September 30, 2020, primarily driven by a decrease in well completion revenues due to the Well Services Exit.

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Expenses and other income (expenses)

The following table summarizes our operating expenses and other income (expenses) for the periods presented (in thousands, except per Boe of production):

	Successor						Predecessor
	Three Months Ended September 30, 2021		Three Months Ended June 30, 2021		Nine Months Ended September 30, 2021			Nine Months Ended September 30, 2020
Operating expenses
Lease operating expenses	$	29,307	$	34,321	$	98,888		$	108,730
Midstream expenses	32,396		23,547		83,841			32,355
Other services expenses	26		21		47			5,968
Gathering, processing and transportation expenses	16,400		20,485		52,596			73,557
Purchased oil and gas expenses	53,880		85,455		187,745			165,932
Production taxes	18,445		16,208		50,933			39,129
Depreciation, depletion and amortization	33,623		38,968		112,581			272,885
Exploration expenses	263		1,250		1,936			3,061
Rig termination	—		—		—			1,279
Impairment	—		2		5			4,828,575
General and administrative expenses	19,514		20,210		60,461			117,868
Litigation settlement	—		—		—			22,750
Total operating expenses	203,854		240,467		649,033			5,672,089
Gain on sale of properties	5,405		222,980		228,473			11,652
Operating income (loss)	203,590		375,573		729,998			(4,835,228)
Other income (expense)
Net gain (loss) on derivative instruments	(101,790)		(267,037)		(550,342)			243,064
Interest expense, net of capitalized interest	(18,153)		(22,571)		(49,421)			(177,534)
Gain on extinguishment of debt	—		—		—			83,867
Reorganization items, net	—		—		—			(49,758)
Other income (expense)	(315)		(1,002)		(859)			2,373
Total other income (expense), net	(120,258)		(290,610)		(600,622)			102,012
Income (loss) before income taxes	83,332		84,963		129,376			(4,733,216)
Income tax benefit	—		(3,654)		—			262,495
Net income (loss) including non-controlling interests	83,332		81,309		129,376			(4,470,721)
Less: Net income (loss) attributable to non-controlling interests	11,382		7,945		27,654			(11,218)
Net income (loss) attributable to Oasis	$	71,950	$	73,364	$	101,722		$	(4,459,503)
Costs and expenses (per Boe of production)
Lease operating expenses	$	6.15	$	6.95	$	6.66		$	5.96
Gathering, processing and transportation expenses	3.44		4.15		3.54			4.03
Production taxes	3.87		3.28		3.43			2.14

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Three months ended September 30, 2021 as compared to three months ended June 30, 2021

Lease operating expenses. LOE decreased $5.0 million to $29.3 million for the three months ended September 30, 2021. This decrease was primarily due to a reduction of $6.4 million in the Permian Basin following the Permian Basin Sale in the second quarter of 2021, partially offset by a $1.3 million increase in LOE in the Williston Basin due to an increase in produced and flowback water volumes and gas lift volumes. LOE per Boe decreased from $6.95 per Boe to $6.15 per Boe primarily due to higher production volumes in the Williston Basin. E&P LOE, which excludes impacts from our midstream business segment, decreased $0.79 to $9.42 per BOE in the third quarter of 2021.

Midstream expenses. Midstream expenses increased $8.9 million during the three months ended September 30, 2021, primarily due to a $7.3 million increase in natural gas purchases from third party producers and a $1.3 million increase in produced and flowback water expenses.

Gathering, processing and transportation expenses. Gathering, processing and transportation (“GPT”) expenses decreased $4.1 million during the three months ended September 30, 2021, primarily due to a decrease of $2.6 million in the Permian Basin following the Permian Basin Sale in the second quarter of 2021, coupled with a $2.3 million decrease due to lower natural gas gathering and transportation expenses in the Williston Basin, partially offset by a $1.1 million increase in crude oil transportation expenses due primarily to an increase in volumes transported on DAPL. GPT per Boe decreased $0.71 to $3.44 for the three months ended September 30, 2021 due to the lower aforementioned costs, coupled with higher production volumes in the Williston Basin. E&P GPT per Boe, which excludes certain impacts from our midstream business segment, decreased to $3.95 for the three months ended September 30, 2021. Cash GPT per Boe, which excludes non-cash valuation adjustments, decreased to $3.56 for the three months ended September 30, 2021. E&P GPT and Cash GPT are non-GAAP financial measures. See “Non-GAAP Financial Measures” below.

Purchased oil and gas expenses. Purchased oil and gas expenses, which represent crude oil purchased to optimize transportation costs, for blending at our crude oil terminal or to cover production shortfalls, decreased $31.6 million to $53.9 million for the three months ended September 30, 2021. This decrease was primarily due to a decrease in crude oil volumes purchased and then subsequently sold in the Williston Basin, coupled with a reduction in purchased oil and gas expenses in the Permian Basin as a result of the Permian Basin Sale in the second quarter of 2021.

Depreciation, depletion and amortization. Depreciation, depletion and amortization (“DD&A”) expenses decreased $5.3 million to $33.6 million for the three months ended September 30, 2021 due to a decrease in the DD&A rate to $4.02 per Boe during the three months ended September 30, 2021, compared to $4.67 per Boe during the three months ended June 30, 2021.

General and administrative (“G&A”) expenses. G&A expenses decreased $0.7 million to $19.5 million for the three months ended September 30, 2021 as compared to the three months ended June 30, 2021 primarily due to lower employee compensation related expenses. In addition, the Company incurred $2.3 million of non-recurring charges during the three months ended September 30, 2021 related to the Williston Basin Acquisition, OMP merger and restructuring consulting expenses.

Gain on sale of properties. For the three months ended September 30, 2021, we recognized a $5.4 million net gain on the sale of properties related to customary post-close adjustments in connection with the Permian Basin Sale. For the three months ended June 30, 2021, we recognized a $223.0 million net gain on the sale of properties primarily related to the Permian Basin Sale, which closed on June 29, 2021.

Derivative instruments. We recorded a $101.8 million net loss on derivative instruments during the three months ended September 30, 2021. The net loss was primarily due to a realized loss of $81.4 million and an unrealized loss of $27.2 million on our commodity derivatives. This was partially offset by an unrealized gain of $6.9 million related to the Permian Basin Sale Contingent Consideration. During the three months ended June 30, 2021, we recorded a $267.0 million net loss on derivative instruments, which included a realized loss on our commodity derivatives of $56.0 million.

Interest expense, net of capitalized interest. Interest expense decreased $4.4 million to $18.2 million for the three months ended September 30, 2021. The decrease was primarily due to fees related to the Oasis Bridge Facility of $7.8 million which were incurred during the three months ended June 30, 2021, partially offset by interest expense under the Oasis Senior Notes which were issued on June 9, 2021.

Income tax benefit (expense). We did not record a provision for income tax during the three months ended September 30, 2021. Our income tax expense for the three months ended June 30, 2021 was recorded at 4.3% of pre-tax income. Our effective tax rate for the three months ended September 30, 2021 of 0.0% was lower than the effective tax rate for the three months ended June 30, 2021 primarily due to the impact of the change in the valuation allowance.

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Nine months ended September 30, 2021 as compared to nine months ended September 30, 2020

Lease operating expenses. LOE decreased $9.8 million to $98.9 million for the nine months ended September 30, 2021 as compared to the nine months ended September 30, 2020. This decrease was primarily due to lower fixed costs, coupled with lower costs due to a decrease in produced and flowback water volumes transported and injected period over period. These decreases were partially offset by higher workover costs period over period. LOE per Boe increased $0.70 per Boe to $6.66 per Boe for the nine months ended September 30, 2021 primarily due to lower production volumes. E&P LOE, which excludes impacts from our midstream business segment, increased $1.92 to $9.86 per Boe for the nine months ended September 30, 2021.

Midstream expenses. Midstream expenses increased $51.5 million during the nine months ended September 30, 2021, primarily due to a $52.7 million increase in natural gas purchases from third party producers, driven by higher residue gas and NGL prices, offset by a $0.8 million decrease in freshwater expenses due to lower completion activity.

Other services expenses. Other services expenses represent third party working interest owners’ share of expenses incurred related to equipment rental services provided to our operated wells, and prior to the Well Services Exit, also included the non-affiliated share of well completion service costs and costs of goods sold. The $5.9 million decrease for the nine months ended September 30, 2021 was primarily attributable to a decrease in well completion expenses due to the Well Services Exit.

Gathering, processing and transportation expenses. GPT expenses decreased $21.0 million period over period, primarily due to a $14.6 million decrease in natural gas gathering and transportation expenses, a $3.3 million decrease in crude oil gathering and transportation expenses, and a $3.0 million decrease in pipeline imbalances. GPT per Boe decreased $0.49 to $3.54 for the nine months ended September 30, 2021 due to the lower aforementioned expenses, offset by lower production volumes. E&P GPT per Boe was $4.02 for the nine months ended September 30, 2021 as compared to $4.27 for the nine months ended September 30, 2020. Cash GPT per Boe decreased to $3.65 for the nine months ended September 30, 2021 as compared to $3.96 for the nine months ended September 30, 2020. E&P GPT and Cash GPT are non-GAAP financial measures. See “Non-GAAP Financial Measures” below.

Purchased oil and gas expenses. Purchased oil and gas expenses increased $21.8 million to $187.7 million for the nine months ended September 30, 2021 as compared to the nine months ended September 30, 2020 primarily due to higher crude oil prices period over period, partially offset by lower crude oil volumes purchased in the Williston Basin and Permian Basin.

Production taxes. Our production taxes as a percentage of crude oil and natural gas sales were 6.5% and 7.6% for the nine months ended September 30, 2021 and 2020, respectively. Production taxes as a percentage of crude oil and natural gas sales decreased period over period primarily due to a lower crude oil production mix in the Williston Basin.

Depreciation, depletion and amortization. DD&A expenses decreased $160.3 million to $112.6 million for the nine months ended September 30, 2021 as compared to the nine months ended September 30, 2020. This decrease was a result of a decrease in the DD&A rate to $7.58 per Boe for the nine months ended September 30, 2021 as compared to $14.96 per Boe for the nine months ended September 30, 2020, coupled with decreased production during the nine months ended September 30, 2021. The decrease in the DD&A rate was primarily due to a lower basis in our proved oil and gas properties as a result of write-downs during 2020.

Exploration expenses. Exploration expenses decreased $1.1 million to $1.9 million for the nine months ended September 30, 2021 as compared to $3.1 million for the nine months ended September 30, 2020. This decrease was primarily due to lower cost write-offs related to exploratory well locations.

Impairment. Impairment expense decreased $4.8 billion for the nine months ended September 30, 2021 as compared to the nine months ended September 30, 2020. There were no material asset impairment charges taken during the nine months ended September 30, 2021. Impairment expense of $4.8 billion for the nine months ended September 30, 2020 was primarily due to the following:

•Proved oil and gas properties. We recorded an impairment charge of $4.4 billion on our proved oil and gas properties, including $3.8 billion in the Williston Basin and $637.3 million in the Permian Basin, for the nine months ended September 30, 2020 primarily due to a significant decline in commodity prices.

•Unproved oil and gas properties. We recorded impairment losses on our unproved oil and gas properties of $293.0 million as a result of leases expiring or expected to expire as well as drilling plan uncertainty on certain acreage of unproved properties.

•Other property and equipment. We recorded impairment charges of $108.8 million to reduce the carrying values of our midstream assets to their estimated fair values as a result of lower forecasted throughput volumes.

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•Assets held for sale. We recorded an impairment loss of $14.5 million to write-off the net book value of certain well services equipment held for sale as of December 31, 2019 for which a sale was no longer probable to be completed within one year. In addition, we recorded an impairment loss of $1.4 million to adjust the carrying value of the remaining equipment held for sale related to the Well Services Exit to its estimated fair value less costs to sell.

•Inventory. We recorded impairment losses of $7.2 million, $1.3 million and $1.0 million to adjust the carrying values of our crude oil inventory, long-term linefill inventory and equipment and materials inventory, respectively, to their net realizable values.

General and administrative expenses. G&A expenses decreased $57.4 million to $60.5 million for the nine months ended September 30, 2021 as compared to the nine months ended September 30, 2020. This decrease was primarily due to lower employee compensation expenses due to a 26% decrease in employee headcount period over period, coupled with restructuring related expenses incurred during the nine months ended September 30, 2020.

Gain on sale of properties. For the nine months ended September 30, 2021, we recognized a $228.5 million gain on sale of properties primarily related to the Permian Basin Sale (see Item 1. “Financial Statements (Unaudited) — Note 10 — Divestitures”). For the nine months ended September 30, 2020, we recognized a $11.7 million gain on sale of properties primarily related to the sale of certain oil and gas properties in the Williston Basin.

Derivative instruments. We recorded a $550.3 million net loss on derivative instruments during the nine months ended September 30, 2021. The net loss was primarily due to an unrealized loss of $397.2 million and a realized loss of $160.0 million on our commodity derivatives. This was partially offset by an unrealized gain of $6.9 million related to the Permian Basin Sale Contingent Consideration. During the nine months ended September 30, 2020, we recorded a $243.1 million net gain on derivative instruments, including net cash settlement receipts of $224.2 million from our commodity derivatives.

Interest expense, net of capitalized interest. Interest expense decreased $128.1 million to $49.4 million for the nine months ended September 30, 2021 as compared to the nine months ended September 30, 2020. During the nine months ended September 30, 2020, we recorded specified default interest charges of $30.3 million and $28.0 million related to the Amended and Restated Credit Agreement, dated October 16, 2018, as amended prior to the Emergence Date and OMP Credit Facility (as defined below), respectively. These specified default interest charges were subsequently waived upon our emergence from bankruptcy in November 2020. In addition, interest expense decreased $77.7 million period over period as a result of the cancellation of the Predecessor senior unsecured notes upon emergence from bankruptcy in 2020, partially offset by interest expense incurred under the Oasis Senior Notes which were issued in the second quarter of 2021. These decreases were offset by an $18.1 million increase in interest expense related to the OMP Senior Notes (as defined below) which were issued in the first quarter of 2021. For the nine months ended September 30, 2021, the weighted average debts outstanding under the Oasis Credit Facility (as defined below) and the OMP Credit Facility were $87.6 million and $290.0 million, respectively, and the weighted average interest rates incurred on the outstanding borrowings were 4.2% and 2.4%, respectively. For the nine months ended September 30, 2020, the weighted average debts outstanding under the Predecessor Credit Facility and the OMP Credit Facility were $450.5 million and $482.7 million, respectively, and the weighted average interest rates incurred on the outstanding borrowings, excluding additional interest charges, were 3.3% and 2.6%, respectively. Interest capitalized during the nine months ended September 30, 2021 and 2020 was $1.5 million and $5.6 million, respectively.

Gain on extinguishment of debt. There was no extinguishment of debt during the nine months ended September 30, 2021. During the nine months ended September 30, 2020, we repurchased an aggregate principal amount of $156.8 million of Predecessor senior unsecured notes for an aggregate cost of $68.0 million and recognized a pre-tax gain of $83.9 million.

Income tax benefit. We did not record a provision for income tax during the nine months ended September 30, 2021. Our income tax benefit was recorded at 5.5% of pre-tax loss for the nine months ended September 30, 2020. Our effective tax rate for the nine months ended September 30, 2021 of 0.0% was lower than the effective tax rate for the nine months ended September 30, 2020 primarily due to the impacts of the change in the valuation allowance and the impacts of non-controlling interests.

Liquidity and Capital Resources

Our primary sources of liquidity during the period covered by this report have been from cash flows from operations, proceeds from the Permian Basin Sale, the issuance of the Oasis Senior Notes and OMP Senior Notes and proceeds from the OMP Equity Offering. Our primary uses of cash have been for net principal payments under our revolving credit facilities, derivative settlements and modifications, the acquisition and development of oil and gas properties and midstream infrastructure, deferred financing costs, interest payments on our long-term debt, dividends paid to our shareholders, share repurchases and distributions to non-controlling interests.

We are committed to a disciplined capital strategy of investing within our cash flows from operations and cash settlements of

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derivative contracts. Our capital allocation committee provides for a rigorous, systematic framework for evaluating and approving capital projects, and we believe our asset base and strong balance sheet will allow us to generate significant free cash flow and corporate-level returns.

Our material cash requirements from known obligations include repayment of outstanding borrowings and interest payment obligations related to long-term debt, obligations to plug, abandon and remediate our oil and gas properties at the end of their productive lives, and obligations associated with our operating and finance leases. In addition, we have contracts which include provisions for the delivery, transport, or purchase of a minimum volume of crude oil, natural gas, NGLs and water within specified time frames, all of which are ten years or less, except for one agreement with a remaining term of approximately 24 years. Under the terms of these contracts, if we fail to deliver, transport or purchase the committed volumes we will be required to pay a deficiency payment for the volumes not tendered over the duration of the contract. However, we believe that our production and reserves are sufficient to fulfill the volume commitments, and therefore, we expect to avoid any material deficiency payments under these contracts. In connection with the Permian Basin Sale, certain of our agreements that contained volume commitments were assigned to Percussion. See “Item 1. — Financial Statements (Unaudited)—Note 18—Commitments and Contingencies” for more information.

As of September 30, 2021, we had $1,481.8 million of liquidity available, including $448.6 million in cash and cash equivalents and $633.2 million of aggregate unused borrowing capacity available under the Oasis Credit Facility and the OMP Credit Facility. At September 30, 2021, we had $400.0 million of restricted cash that was held in a standalone account and was used to fund a portion of the Williston Basin Acquisition that closed on October 21, 2021.

Oasis Credit Facility. We have a reserves-based credit agreement (the “Oasis Credit Facility”), which has an overall senior secured line of credit of $1,500.0 million, an aggregate amount of elected commitments of $450.0 million and a borrowing base of $400.0 million at September 30, 2021. On October 21, 2021, we entered into the Fifth Amendment to the Oasis Credit Facility (the “Fifth Amendment”). In connection with the Fifth Amendment, the semi-annual redetermination of the borrowing base was completed, which increased the borrowing base to $900.0 million and reaffirmed the aggregate amount of elected commitments of $450.0 million. The Oasis Credit Facility has a maturity date of May 19, 2024. See “Item 1. — Financial Statements (Unaudited)—Note 11—Long-Term Debt” for more information.

As of September 30, 2021, we had no borrowings outstanding and $1.3 million of outstanding letters of credit under the Oasis Credit Facility, resulting in an unused borrowing capacity of $398.7 million. During the three months ended September 30, 2021, there were no borrowings outstanding under the Oasis Credit Facility. For the nine months ended September 30, 2021, the weighted average interest rate incurred on borrowings under the Oasis Credit Facility was 4.2%. The Company was in compliance with the financial covenants of the Oasis Credit Facility at September 30, 2021.

Oasis Senior Notes. On June 9, 2021, we issued in a private placement $400.0 million of 6.375% senior unsecured notes due June 1, 2026. The Oasis Senior Notes were issued at par and resulted in net proceeds of $393.0 million. We used the proceeds from the Oasis Senior Notes offering to fund a portion of the Williston Basin Acquisition. Interest on the Oasis Senior Notes is payable semi-annually on June 1 and December 1 of each year, commencing on December 1, 2021. See “Item 1. — Financial Statements (Unaudited)—Note 11—Long-Term Debt” for more information.

OMP Credit Facility. We consolidate OMP and include OMP’s revolving credit facility (the “OMP Credit Facility”) in our condensed consolidated financial statements. OMP uses this credit facility to fund working capital and to finance acquisitions and other capital expenditures. The OMP Credit Facility does not mature until at least September 30, 2024. On March 22, 2021, OMP entered into the Fourth Amendment to the OMP Credit Facility. See “Item 1. — Financial Statements (Unaudited)—Note 11—Long-Term Debt” for more information.

As of September 30, 2021, the OMP Credit Facility had an aggregate amount of commitments of $450.0 million with $210.0 million of outstanding borrowings and $5.5 million of outstanding letters of credit, resulting in an unused borrowing capacity of $234.5 million. For the three and nine months ended September 30, 2021, the weighted average interest rate incurred on borrowings under the OMP Credit Facility was 2.5% and 2.4%, respectively. OMP was in compliance with the financial covenants of the OMP Credit Facility at September 30, 2021.

OMP Senior Notes. On March 30, 2021, OMP issued in a private placement $450.0 million of 8.00% senior unsecured notes due April 1, 2029 (the “OMP Senior Notes”). The OMP Senior Notes were issued at par and resulted in net proceeds of $442.1 million, which OMP used to (i) make a distribution of $231.5 million to Oasis in connection with the Midstream Simplification, (ii) repay approximately $204.0 million of outstanding principal borrowings under the OMP Credit Facility and $0.5 million of accrued interest under the OMP Credit Facility and (iii) pay approximately $6.1 million in fees and other expenses. Interest on the OMP Senior Notes is payable semi-annually on April 1 and October 1 of each year, commencing on October 1, 2021. See “Item 1. — Financial Statements (Unaudited)—Note 11—Long-Term Debt” for more information.

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OMP Equity Offering. On June 29, 2021, OMP completed an underwritten public offering of 3,623,188 common units representing limited partnership interests at a price to the public of $24.00 per common unit and received net proceeds of $86.7 million, after deducting underwriting discounts and commissions. OMP used the proceeds from the OMP Equity Offering to redeem 3,623,188 common units held by Oasis for $87.0 million. Following the OMP Unit Redemption, the Company owns approximately 70% of OMP’s outstanding common units.

Cash flows

Our cash flows for the nine months ended September 30, 2021 and 2020 are presented below (in thousands):

	Successor		Predecessor
	Nine months ended September 30, 2021		Nine Months Ended September 30, 2020
Net cash provided by operating activities	$	644,746	$	154,905
Net cash used in investing activities	(89,031)		(52,365)
Net cash provided by (used in) financing activities	272,667		(38,294)
Increase in cash, cash equivalents and restricted cash	$	828,382	$	64,246

Cash flows provided by operating activities

Net cash provided by operating activities was $644.7 million for the nine months ended September 30, 2021. The increase in net cash provided by operating activities from the nine months ended September 30, 2020 was due primarily to higher crude oil and natural gas revenues, coupled with lower interest expense related to the cancellation of the Predecessor senior unsecured notes. In addition, G&A, GPT and LOE expenses decreased period over period. Refer to “Results of Operations” above for more information on the impact of volumes and prices on revenues and for more information on increases and decreases in certain expenses between periods.

Working capital. Our working capital fluctuates primarily as a result of changes in commodity pricing and production volumes, capital spending to fund development of our oil and gas properties and the impact of our outstanding derivative instruments. We had a working capital surplus of $88.2 million and a working capital deficit of $69.6 million at September 30, 2021 and December 31, 2020, respectively. We believe we have adequate liquidity to meet our working capital requirements. Our working capital increased due to higher cash and cash equivalents and accounts receivable, partially offset by increases in the net liability related to our short-term derivative instruments, accrued liabilities and revenues and production taxes payable.

Cash flows used in investing activities

Net cash used in investing activities was $89.0 million for the nine months ended September 30, 2021. The increase in net cash used in investing activities from the nine months ended September 30, 2020 was primarily due to payments made related to the settlement of outstanding commodity derivatives, coupled with a deposit made in connection with the Williston Basin Acquisition, offset by proceeds from the Permian Basin Sale and a decrease in cash capital expenditures, primarily for drilling and development costs.

Cash flows provided by (used in) financing activities

Net cash provided by financing activities was $272.7 million for the nine months ended September 30, 2021, which increased from net cash used in financing activities for the nine months ended September 30, 2020. The increase in cash flows from financing activities was primarily due to the issuance of the Oasis Senior Notes and OMP Senior Notes, partially offset by the net principal repayments of outstanding borrowings under the Oasis Credit Facility and OMP Credit Facility.

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Capital expenditures

Our capital expenditures are summarized in the following table:

	Three Months Ended						Nine Months Ended
	March 31, 2021		June 30, 2021		September 30, 2021		September 30, 2021
	(In thousands)
Capital expenditures:
E&P	$	28,595	$	52,355	$	41,945	$	122,895
Other capital expenditures(1)	414		660		606		1,680
Total E&P and other capital expenditures	29,009		53,015		42,551		124,575
Midstream	259		13,392		16,135		29,786
Total capital expenditures(2)	$	29,268	$	66,407	$	58,686	$	154,361

___________________

(1)Other capital expenditures include such items as administrative capital and capitalized interest. Capitalized interest totaled $0.6 million and $1.5 million for the three and nine months ended September 30, 2021.

(2)Total capital expenditures reflected in the table above differs from the amounts shown in the statements of cash flows in our unaudited condensed consolidated financial statements because amounts reflected in the table include changes in accrued liabilities from the previous reporting period for capital expenditures, while the amounts presented in the statements of cash flows are presented on a cash basis.

Dividends

We have paid quarterly cash dividends totaling $22.5 million during 2021. In addition, we paid a special dividend of $4.00 per share of common stock on July 21, 2021 totaling $80.0 million. On October 26, 2021, we declared a dividend of $0.50 per share of common stock payable on November 29, 2021 to shareholders of record as of November 15, 2021.

Future dividend payments will depend on the Company’s earnings, financial condition, capital requirements, level of indebtedness, statutory and contractual restrictions applicable to the payment of dividends and other considerations that the Board of Directors deems relevant.

Share Repurchase Program

In March 2021, the Board of Directors authorized a share-repurchase program covering up to $100.0 million of the Company's common stock which expires on December 31, 2022.

During the nine months ended September 30, 2021, the Company repurchased 190,783 shares of common stock at a weighted average price of $76.30 per common share for a total cost of $14.6 million. There were no share repurchases made subsequent to September 30, 2021, except from October 28, 2021 through November 2, 2021, the Company repurchased 156,519 shares of common stock at a weighted average price of $121.22 per common share for a total cost of $19.0 million.

Tax Benefits Preservation Plan

The Company has determined that it qualifies for an exception to the limitation on its net operating loss carryforwards (“NOLs”) and other tax attributes (collectively, the “Tax Benefits”) under Section 382(l)(5) of the Internal Revenue Code (the “Code”), as of its emergence from Chapter 11 restructuring. This qualification resulted in reducing cash taxes to zero for the nine months ended September 30, 2021, and we do not expect to owe cash taxes for the fiscal year ending December 31, 2021.

Under Section 382(l)(5) of the Code, if the Company were to experience an “ownership change” as defined by Section 382 of the Code within the two-year period immediately following the Emergence Date, the Company would be precluded from utilizing the Tax Benefits following such ownership change. If Oasis is unable to use its Tax Benefits in years in which the Company has taxable income, the Company will pay significantly more in cash tax than if it were able to utilize the Tax Benefits, and those tax costs would negatively impact the Company’s financial position, results of operations and cash flows. As a result, the Board of Directors has adopted a Tax Benefits Preservation Plan (the “Tax Plan”) designed to protect the availability of the Company’s Tax Benefits, which may be utilized in certain circumstances to reduce the Company’s future income tax obligations. The Tax Plan reduces the likelihood that any changes in the Company’s investor base, including an ownership change, would limit the Company’s future use of its Tax Benefits.

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In adopting the Tax Plan, the Board of Directors declared a dividend of one preferred share purchase right (a “Right”) for each outstanding share of the Company’s common stock. The Rights will trade with the Company’s common stock and will expire at the close of business on the earlier of August 3, 2024 (three years from adoption) and the date upon which the Board of Directors determines that no Tax Benefits remain available or earlier as described in more detail in the Tax Plan. The Rights will be exercisable if, among other things, a person or group of persons acquires 4.95% or more of the Company’s outstanding common stock.

The Tax Plan adopted by the Board of Directors is similar to plans adopted by other publicly-held companies with significant NOLs or other substantial tax benefits and is not designed to prevent any action that the Board of Directors determines to be in the best interest of the Company and its shareholders. The Company expects to submit the Tax Plan for ratification by the Company’s shareholders at the Company’s 2022 Annual Meeting. For more information regarding the Company’s Tax Benefits, please refer to the 2020 Annual Report.

Non-GAAP Financial Measures

The following measures described below are supplemental non-GAAP financial measures that are used by management and external users of our financial statements, such as industry analysts, investors, lenders and rating agencies. These non-GAAP financial measures should not be considered in isolation or as a substitute for gas revenues, GPT expenses, G&A expenses, interest expense, net income (loss), operating income (loss) and net cash provided by (used in) operating activities or any other measures prepared under GAAP. Because these non-GAAP financial measures exclude some but not all items that affect net income (loss) and may vary among companies, the amounts presented may not be comparable to similar metrics of other companies.

E&P Adjusted Gas Revenue

We define E&P Adjusted Gas Revenue as total natural gas revenues less benefits from our midstream business segment related to natural gas gathering and processing services recorded to consolidated GPT expenses. E&P Adjusted Gas Revenue is not a measure of natural gas revenues as determined by GAAP. Management believes that the presentation of E&P Adjusted Gas Revenue provides useful additional information to investors and analysts to evaluate the natural gas revenues derived from our E&P business. This non-GAAP measure is intended to provide investors and analysts an indication of the natural gas revenues we would receive if our natural gas volumes were serviced by a third-party midstream operator.

The following table presents a reconciliation of the GAAP financial measure of natural gas revenues to the non-GAAP financial measure of E&P Adjusted Gas Revenue for the periods presented (in thousands):

	Successor		Predecessor		Successor		Predecessor
	Three Months Ended September 30, 2021		Three Months Ended September 30, 2020		Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020
Natural gas revenues	$	75,905	$	24,525	$	184,046	$	63,631
Intercompany impacts from midstream segment	(11,773)		(9,710)		(32,869)		(26,579)
E&P Adjusted Gas Revenue	$	64,132	$	14,815	$	151,177	$	37,052

Cash GPT and E&P GPT

We define Cash GPT as total GPT expenses less non-cash valuation charges on pipeline imbalances. We define E&P GPT as Cash GPT less the benefits from our midstream business segment related to crude oil gathering and transportation services. Cash GPT and E&P GPT are not measures of GPT expenses as determined by GAAP. Management believes that the presentation of Cash GPT and E&P GPT provide useful additional information to investors and analysts to assess the cash costs incurred to market and transport our commodities from the wellhead to delivery points for sale without regard for certain benefits of our midstream business segment, as well as the change in value of our pipeline imbalances, which vary monthly based on commodity prices.

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The following table presents a reconciliation of the GAAP financial measure of GPT expenses to the non-GAAP financial measures of Cash GPT and E&P GPT for the periods presented (in thousands):

	Successor		Predecessor	Successor				Predecessor
	Three Months Ended September 30, 2021			Three Months Ended September 30, 2020		Nine Months Ended September 30, 2021			Nine Months Ended September 30, 2020
GPT	$	16,400		$	20,328	$	52,596		$	73,557
Pipeline imbalances	547			90		1,656			(1,377)
Cash GPT	16,947			20,418		54,252			72,180
Intercompany impacts from midstream segment	1,856			1,965		5,455			5,761
E&P GPT	$	18,803		$	22,383	$	59,707		$	77,941

E&P Cash G&A

We define E&P Cash G&A as total G&A expenses less non-cash equity-based compensation expenses, other non-cash charges and G&A expenses attributable to our midstream business segment. E&P Cash G&A is not a measure of G&A expenses as determined by GAAP. Management believes that the presentation of E&P Cash G&A provides useful additional information to investors and analysts to assess our operating costs in comparison to peers without regard to equity-based compensation programs, which can vary substantially from company to company.

The following table presents a reconciliation of the GAAP financial measure of G&A expenses to the non-GAAP financial measure of E&P Cash G&A for the periods presented (in thousands):

	Successor		Predecessor		Successor		Predecessor
	Three Months Ended September 30, 2021		Three Months Ended September 30, 2020		Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020
General and administrative expenses	$	19,514	$	49,251	$	60,461	$	117,868
Equity-based compensation expenses	(4,287)		(4,502)		(11,187)		(15,861)
G&A expenses attributable to midstream segment	(3,670)		(5,317)		(12,709)		(17,128)
Other non-cash adjustments	(1,025)		983		(675)		560
E&P Cash G&A	$	10,532	$	40,415	$	35,890	$	85,439

Cash Interest and E&P Cash Interest

We define Cash Interest as interest expense plus capitalized interest less amortization and write-offs of deferred financing costs and debt discounts included in interest expense, and E&P Cash Interest is defined as total Cash Interest less Cash Interest attributable to OMP. Cash Interest and E&P Cash Interest are not measures of interest expense as determined by GAAP. Management believes that the presentation of Cash Interest and E&P Cash Interest provide useful additional information to investors and analysts for assessing the interest charges incurred on our debt to finance our E&P activities, excluding non-cash amortization, and our ability to maintain compliance with our debt covenants.

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The following table presents a reconciliation of the GAAP financial measure of interest expense to the non-GAAP financial measures of Cash Interest and E&P Cash Interest for the periods presented (in thousands):

	Successor		Predecessor		Successor		Predecessor
	Three Months Ended September 30, 2021		Three Months Ended September 30, 2020		Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020(1)
Interest expense	$	18,153	$	37,389	$	49,421	$	177,534
Capitalized interest	578		1,572		1,539		5,635
Amortization of deferred financing costs(2)	(1,216)		(1,443)		(14,677)		(7,590)
Amortization of debt discount	—		(2,782)		—		(8,317)
Cash Interest	17,515		34,736		36,283		167,262
Cash Interest attributable to OMP	(10,606)		(2,481)		(24,091)		(37,694)
E&P Cash Interest	$	6,909	$	32,255	$	12,192	$	129,568

___________________

(1)For the nine months ended September 30, 2020, interest expense, Cash Interest and E&P Cash Interest include a specified default interest charge of $30.3 million related to the Predecessor Credit Facility. For the nine months ended September 30, 2020, interest expense, Cash Interest and Cash Interest attributable to OMP include a specified default interest charge of $28.0 million related to the OMP Credit Facility. These specified default interest charges were waived upon our emergence from bankruptcy on November 19, 2020.

(2)The nine months ended September 30, 2021 includes $7.8 million of fees associated with a bridge loan facility which were expensed as incurred. See “Item 1. — Financial Statements (Unaudited)—Note 11—Long-Term Debt” for more information.

Adjusted EBITDA and Adjusted EBITDA attributable to Oasis

We define Adjusted EBITDA as earnings (loss) before interest expense, income taxes, DD&A, exploration expenses and other similar non-cash or non-recurring charges. We define Adjusted EBITDA attributable to Oasis as Adjusted EBITDA less Adjusted EBITDA attributable to OMP, plus distributions from OMP for our ownership of OMP limited partner units and, prior to the Midstream Simplification, Adjusted EBITDA attributable to our retained interests in Bobcat DevCo and Beartooth DevCo (the “DevCo Interests”) and distributions from OMP GP related to OMP’s incentive distribution rights.

Adjusted EBITDA and Adjusted EBITDA attributable to Oasis are not measures of net income (loss) or cash flows as determined by GAAP. Management believes that the presentation of Adjusted EBITDA and Adjusted EBITDA to Oasis provides useful additional information to investors and analysts for assessing our results of operations, financial performance, ability to generate cash from our business operations without regard to our financing methods or capital structure and, with respect to Adjusted EBITDA attributable to Oasis, our ability to maintain compliance with our debt covenants under the Oasis Credit Facility.

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The following table presents reconciliations of the GAAP financial measures of net loss including non-controlling interests and net cash provided by operating activities to the non-GAAP financial measures of Adjusted EBITDA and Adjusted EBITDA attributable to Oasis for the periods presented (in thousands):

	Successor		Predecessor		Successor		Predecessor
	Three Months Ended September 30, 2021		Three Months Ended September 30, 2020		Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020
Net income (loss) including non-controlling interests	$	83,332	$	(47,097)	$	129,376	$	(4,470,721)
Gain on sale of properties	(5,405)		(1,473)		(228,473)		(11,652)
(Gain) loss on extinguishment of debt	—		20		—		(83,867)
Net (gain) loss on derivative instruments	101,790		5,071		550,342		(243,064)
Derivative settlements	(81,443)		80,154		(160,018)		224,223
Interest expense, net of capitalized interest(1)	18,153		37,389		49,421		177,534
Depreciation, depletion and amortization	33,623		36,000		112,581		272,885
Impairment	—		2,578		5		4,828,575
Rig termination	—		1,017		—		1,279
Exploration expenses	263		725		1,936		3,061
Equity-based compensation expenses	4,287		4,834		11,187		16,531
Litigation settlement	—		22,750		—		22,750
Reorganization items, net	—		49,758		—		49,758
Income tax benefit	—		(5,144)		—		(262,495)
Other non-cash adjustments	816		104		164		3,114
Adjusted EBITDA	155,416		186,686		466,521		527,911
Adjusted EBITDA attributable to OMP	(58,178)		(57,106)		(170,456)		(170,054)
Adjusted EBITDA attributable to DevCo Interests	—		19,808		—		60,553
Cash distributions from OMP to Oasis(2)	18,954		13,266		52,828		39,774
Adjusted EBITDA attributable to Oasis	$	116,192	$	162,654	$	348,893	$	458,184
Net cash provided by operating activities	$	294,383	$	95,010	$	644,746	$	154,905
Derivative settlements	(81,443)		80,154		(160,018)		224,223
Interest expense, net of capitalized interest(1)	18,153		37,389		49,421		177,534
Rig termination	—		1,017		—		1,279
Exploration expenses	263		725		1,936		3,061
Deferred financing costs amortization and other	(2,523)		(2,286)		(18,811)		(19,041)
Current tax benefit	—		—		—		(36)
Changes in working capital	(74,233)		(48,177)		(50,917)		(39,878)
Litigation settlement	—		22,750		—		22,750
Other non-cash adjustments	816		104		164		3,114
Adjusted EBITDA	155,416		186,686		466,521		527,911
Adjusted EBITDA attributable to OMP	(58,178)		(57,106)		(170,456)		(170,054)
Adjusted EBITDA attributable to DevCo interests	—		19,808		—		60,553
Cash distributions from OMP to Oasis	18,954		13,266		52,828		39,774
Adjusted EBITDA attributable to Oasis	$	116,192	$	162,654	$	348,893	$	458,184

___________________

(1)For the nine months ended September 30, 2020, interest expense includes specified default interest charges of $30.3 million related to the Predecessor Credit Facility and $28.0 million related to the OMP Credit Facility. These specified default interest charges were waived upon our emergence from bankruptcy on November 19, 2020.

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E&P Adjusted EBITDA and E&P Free Cash Flow

We define E&P Free Cash Flow as Adjusted EBITDA from our E&P segment plus distributions to Oasis for (i) our ownership of OMP limited partner units and, prior to the Midstream Simplification, (ii) distributions from OMP GP related to OMP’s incentive distribution rights and (iii) the DevCo Interests; less E&P Cash Interest, capital expenditures for E&P and other, excluding capitalized interest, and midstream capital expenditures attributable to the DevCo Interests. E&P Free Cash Flow is not a measure of net income (loss) or cash flows as determined by GAAP. Management believes that the presentation of E&P Free Cash Flow provides useful additional information to investors and analysts for assessing the financial performance of our E&P business as compared to our peers and our ability to generate cash from our E&P operations and midstream ownership interests after interest and capital spending. In addition, E&P Free Cash Flow excludes changes in operating assets and liabilities that relate to the timing of cash receipts and disbursements, which we may not control, and changes in operating assets and liabilities may not relate to the period in which the operating activities occurred.

The following table presents a reconciliation of the GAAP financial measure of loss before income taxes including non-controlling interests from our E&P segment to the non-GAAP financial measure of Adjusted EBITDA from our E&P segment and E&P Free Cash Flow for the periods presented (in thousands):

	Successor		Predecessor		Successor		Predecessor
	Three Months Ended September 30, 2021		Three Months Ended September 30, 2020		Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020
Income (loss) before income taxes including non-controlling interests	$	44,040	$	(96,556)	$	18,910	$	(4,726,179)
Gain on sale of properties	(5,399)		(1,473)		(233,502)		(11,652)
(Gain) loss on extinguishment of debt	—		20		—		(83,867)
Net (gain) loss on derivative instruments	101,790		5,071		550,342		(243,064)
Derivative settlements	(81,443)		80,154		(160,018)		224,223
Interest expense, net of capitalized interest(1)	7,156		34,636		23,445		139,338
Depreciation, depletion and amortization	23,974		31,175		83,976		255,505
Impairment	—		992		3		4,717,306
Exploration expenses	263		463		1,936		3,061
Rig termination	—		1,279		—		1,279
Equity-based compensation	4,144		4,502		10,518		15,909
Litigation settlement	—		22,750		—		22,750
Reorganization items, net	—		49,758		—		49,758
Other non-cash adjustments	816		104		185		3,114
E&P Adjusted EBITDA	95,341		132,875		295,795		367,481
Distributions to Oasis from OMP and DevCo Interests(2)	18,954		33,070		52,828		100,320
E&P Cash Interest(1)	(6,909)		(32,255)		(12,192)		(129,568)
E&P and other capital expenditures	(42,551)		(10,223)		(124,575)		(202,507)
Midstream capital expenditures attributable to DevCo Interests	—		1,246		—		(6,467)
Capitalized interest	578		1,572		1,539		5,635
E&P Free Cash Flow(1)	$	65,413	$	126,285	$	213,395	$	134,894

___________________

(1)For the nine months ended September 30, 2020, interest expense, E&P Cash Interest and E&P Free Cash Flow include the impact of a specified default interest charge related to the Predecessor Credit Facility of $30.3 million. The specified default interest was waived upon our emergence from bankruptcy on November 19, 2020.

(2)There were no distributions to Oasis from DevCo Interests subsequent to the Midstream Simplification. See “Recent Developments – Midstream Simplification” above for more information.

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Fair Value of Financial Instruments

See “Item 1. Financial Statements (Unaudited)—Note 6—Fair Value Measurements” for a discussion of our derivative instruments and their related fair value measurements. See also “Item 3. Quantitative and Qualitative Disclosures about Market Risk” below.

Critical Accounting Policies and Estimates

There have been no material changes in our critical accounting policies and estimates from those disclosed in our 2020 Annual Report.

Item 3. — Quantitative and Qualitative Disclosures about Market Risk

We are exposed to a variety of market risks, including commodity price risk, interest rate risk and counterparty and customer risk. We address these risks through a program of risk management, including the use of derivative instruments.

The primary objective of the following information is to provide forward-looking quantitative and qualitative information about our potential exposure to market risk. The term “market risk” refers to the risk of loss arising from adverse changes in crude oil, natural gas and NGL prices and interest rates. The disclosures are not meant to be precise indicators of expected future losses, but rather indicators of reasonably possible losses. This forward-looking information provides indicators of how we view and manage our ongoing market risk exposures. All of our market risk sensitive instruments were entered into for hedging purposes, rather than for speculative trading. The following market risk disclosures should be read in conjunction with the quantitative and qualitative disclosures about market risk contained in our 2020 Annual Report, as well as with the unaudited condensed consolidated financial statements and notes thereto included in this Quarterly Report on Form 10-Q.

Commodity price exposure risk. We are exposed to market risk as the prices of crude oil, natural gas and NGLs fluctuate as a result of a variety of factors, including changes in supply and demand and the macroeconomic environment, all of which are typically beyond our control. The markets for crude oil, natural gas and NGLs have been volatile, especially over the last several months and years. These prices will likely continue to be volatile in the future. To partially reduce price risk caused by these market fluctuations, we have entered into commodity derivative contracts in the past and expect to enter into derivative instruments in the future. Additionally, we may choose to liquidate existing derivative positions before the contract ends in order to realize the current value of our existing positions, in accordance with terms under our credit agreements.

In addition, pursuant to the purchase and sale agreement associated with the Primary Permian Basin Sale, the Company is entitled to receive up to three earn-out payments of $25.0 million per year for each of 2023, 2024 and 2025 if the average daily settlement price of NYMEX WTI crude oil exceeds $60 per barrel for such year. If the NYMEX WTI crude oil price for calendar year 2023 or 2024 is less than $45 per barrel, then each calendar year thereafter Percussion’s obligation to make any remaining earn-out payments is terminated.

We had a net derivative liability position of $408.9 million at September 30, 2021. A 10% increase in crude oil prices would decrease the fair value of our derivative position by approximately $158.7 million, while a 10% decrease in crude oil prices would increase the fair value by approximately $153.6 million. See “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Recent Developments—Market Conditions and COVID-19,” for further discussion on the commodity price environment. See “Item 1. Financial Statements (Unaudited)—Note 7—Derivative Instruments” to our unaudited condensed consolidated financial statements for additional information regarding our derivative instruments.

Interest rate risk. At September 30, 2021, we had $400.0 million of Oasis Senior Notes outstanding at a fixed cash interest rate of 6.375% per annum and $450.0 million of OMP Senior Notes outstanding at a fixed cash interest rate of 8.00% per annum.

At September 30, 2021, we had no borrowings and $1.3 million of outstanding letters of credit under the Oasis Credit Facility. Borrowings under the Oasis Credit Facility are subject to varying rates of interest based on (i) the total outstanding borrowings (including the value of all outstanding letters of credit) in relation to the borrowing base and (ii) whether the loan is a London interbank offered rate (“LIBOR”) loan (“Eurodollar Loan”) or a domestic bank prime interest rate loan (“ABR Loan”). The unused borrowing base capacity is subject to a commitment fee of 0.500%.

At September 30, 2021, OMP had $210.0 million of borrowings and $5.5 million of outstanding letters of credit under the OMP Credit Facility, which were subject to varying rates of interest based on (i) OMP’s most recently tested consolidated total leverage ratio and (ii) whether the loan is a Eurodollar Loan or an ABR Loan. The unused portion of the OMP Credit Facility is subject to a commitment fee ranging from 0.375% to 0.500%. At September 30, 2021, the outstanding borrowings under the OMP Credit Facility bore interest at LIBOR plus a 2.25% margin.

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We do not currently, but may in the future, utilize interest rate derivatives to mitigate interest rate exposure in an attempt to reduce interest rate expense related to debt issued under the Oasis Credit Facility or the OMP Credit Facility. Interest rate derivatives would be used solely to modify interest rate exposure and not to modify the overall leverage of the debt portfolio.

Counterparty and customer credit risk. Joint interest receivables arise from billing entities which own partial interest in the wells we operate. These entities participate in our wells primarily based on their ownership in leases on which we choose to drill. We have limited ability to control participation in our wells. For the three and nine months ended September 30, 2021, our credit losses on joint interest receivables were immaterial. We are also subject to credit risk due to concentration of our crude oil and natural gas receivables with several significant customers. The inability or failure of our significant customers to meet their obligations to us, or their insolvency or liquidation, may adversely affect our financial results.

We monitor our exposure to counterparties on crude oil and natural gas sales primarily by reviewing credit ratings, financial statements and payment history. We extend credit terms based on our evaluation of each counterparty’s credit worthiness. We have not generally required our counterparties to provide collateral to secure crude oil and natural gas sales receivables owed to us. Historically, our credit losses on crude oil and natural gas sales receivables have been immaterial.

In addition, our crude oil and natural gas derivative arrangements expose us to credit risk in the event of nonperformance by counterparties. However, in order to mitigate the risk of nonperformance, we only enter into derivative contracts with counterparties that are high credit-quality financial institutions. All of the counterparties on our derivative instruments currently in place are lenders under the Oasis Credit Facility with investment grade ratings. We are likely to enter into any future derivative instruments with these or other lenders under the Oasis Credit Facility, which also carry investment grade ratings. This risk is also managed by spreading our derivative exposure across several institutions and limiting the volumes placed under individual contracts. Furthermore, the agreements with each of the counterparties on our derivative instruments contain netting provisions. As a result of these netting provisions, our maximum amount of loss due to credit risk is limited to the net amounts due to and from the counterparties under the derivative contracts.

Item 4. — Controls and Procedures

Evaluation of disclosure controls and procedures

As required by Rule 13a-15(b) of the Exchange Act, we have evaluated, under the supervision and with the participation of our management, including our Chief Executive Officer (“CEO”), our principal executive officer, and our Chief Financial Officer (“CFO”), our principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of September 30, 2021. Our disclosure controls and procedures are designed to provide reasonable assurance that information required to be disclosed by us in the reports filed or submitted by us under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our CEO and CFO as appropriate, to allow timely decisions regarding required disclosure. Based on this evaluation, our CEO and CFO concluded that the Company’s disclosure controls and procedures were effective as of September 30, 2021.

Changes in internal control over financial reporting

There were no changes in our internal control over financial reporting that occurred during the quarter ended September 30, 2021 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II — OTHER INFORMATION

Item 1. — Legal Proceedings

See “Part I, Item 1. — Financial Statements (Unaudited) — Note 18 — Commitments and Contingencies” which is incorporated herein by reference, for a discussion of material legal proceedings.

Item 1A. — Risk Factors

Our business faces many risks. Any of the risks discussed elsewhere in this Form 10-Q and our other SEC filings could have a material impact on our business, financial position or results of operations. Additional risks and uncertainties not presently known to us or that we currently believe to be immaterial may also impair our business operations.

For a discussion of our potential risks and uncertainties, see the information in “Part I. Item 1A. Risk Factors” in our 2020 Annual Report. There have been no material changes in our risk factors from those described in our 2020 Annual Report and subsequent SEC filings.

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Item 2. — Unregistered Sales of Equity Securities and Use of Proceeds

Unregistered sales of equity securities. There were no sales of unregistered equity securities during the period covered by this report.

Issuer purchases of equity securities. The following table contains information about our acquisition of equity securities during the three months ended September 30, 2021:

Period	Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs (1)	Maximum Number (or Approximate Dollar Value) of Shares that May Be Purchased Under the Plans or Programs
July 1 – July 31, 2021	—	$	85,443,582
August 1 – August 31, 2021	—	85,443,582
September 1 – September 30, 2021	—	85,443,582
Total	—	$	85,443,582

___________________ 

(1)In March 2021, the Board of Directors authorized a share-repurchase program covering up to $100.0 million of the Company's common stock. This share-repurchase program expires on December 31, 2022.

During the three months ended September 30, 2021, no shares of common stock were surrendered by the Company’s employees to satisfy tax withholding obligations arising from vesting of restricted stock awards.

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Item 6. — Exhibits

Exhibit No.	Description of Exhibit
2.1	Agreement and Plan of Merger, dated October 25, 2021, by and among Crestwood Equity Partners LP, Project Falcon Merger Sub LLC, Project Phantom Merger Sub LLC, Oasis Midstream Partners LP, OMP GP LLC and, solely for purposes of Section 2.1(a)(i), Crestwood Equity GP LLC (filed as Exhibit 2.1 to the Company’s Current Report on Form 8-K on October 28, 2021, and incorporated herein by reference).
3.1	Certificate of Designations of Series A Junior Participating Preferred Stock of Oasis Petroleum Inc. (filed as Exhibit 3.1 to the Company’s Current Report on Form 8-K on August 4, 2021, and incorporated herein by reference).
4.1	Tax Benefits Preservation Plan, dated as of August 3, 2021, by and between Oasis Petroleum Inc. and Computershare Trust Company, N.A., as Rights Agent (filed as Exhibit 4.1 to the Company’s Current Report on Form 8-K on August 4, 2021, and incorporated herein by reference).
10.1	Support Agreement, dated October 25, 2021, by and among Crestwood Equity Partners LP, Oasis Midstream Partners LP, Oasis Petroleum Inc., OMP GP LLC and OMS Holdings LLC (filed as Exhibit 10.1 to the Company’s Current Report on Form 8-K on October 28, 2021, and incorporated herein by reference).
31.1(a)	Sarbanes-Oxley Section 302 certification of Principal Executive Officer.
31.2(a)	Sarbanes-Oxley Section 302 certification of Principal Financial Officer.
32.1(b)	Sarbanes-Oxley Section 906 certification of Principal Executive Officer.
32.2(b)	Sarbanes-Oxley Section 906 certification of Principal Financial Officer.
101.INS(a)	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(a)	XBRL Schema Document.
101.CAL(a)	XBRL Calculation Linkbase Document.
101.DEF(a)	XBRL Definition Linkbase Document.
101.LAB(a)	XBRL Label Linkbase Document.
101.PRE(a)	XBRL Presentation Linkbase Document.
104(a)	Cover Page Interactive Data File - the cover page interactive data file does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

___________________

(a)Filed herewith.

(b)Furnished herewith.

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SIGNATURES

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.

			OASIS PETROLEUM INC.
Date:	November 4, 2021	By:	/s/ Daniel E. Brown
			Daniel E. Brown
			Chief Executive Officer (Principal Executive Officer)

By:	/s/ Michael H. Lou
	Michael H. Lou
	Executive Vice President and Chief Financial Officer (Principal Financial Officer and Principal Accounting Officer)

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