10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

    For the quarterly period ended September 30, 2023

or

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

    For the transition period from ____________ to ____________

Commission File Number 001-14039

Callon Petroleum Company

(Exact Name of Registrant as Specified in Its Charter)

Delaware		64-0844345
State or Other Jurisdiction of Incorporation or Organization		I.R.S. Employer Identification No.
One Briarlake Plaza
2000 W. Sam Houston Parkway S., Suite 2000
Houston,	Texas	77042
Address of Principal Executive Offices		Zip Code

(281)	589-5200
Registrant’s Telephone Number, Including Area Code
Former Name, Former Address and Former Fiscal Year, if Changed Since Last Report

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, $0.01 par value	CPE	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ 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, 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 ☒

The Registrant had 67,773,848 shares of common stock outstanding as of October 27, 2023.

For certain industry specific terms used in this Quarterly Report on Form 10-Q (this “Form 10-Q”), please see “Glossary of Certain Terms” in our Annual Report on Form 10-K for the year ended December 31, 2022 (“2022 Annual Report”).

Table of Contents

Part I. Financial Information
Item 1. Financial Statements (Unaudited)
Consolidated Balance Sheets	3
Consolidated Statements of Operations	4
Consolidated Statements of Stockholders’ Equity	5
Consolidated Statements of Cash Flows	6
Notes to Consolidated Financial Statements	7
Item 2.  Management’s Discussion and Analysis of Financial Condition and Results of Operations	26
Item 3.  Quantitative and Qualitative Disclosures about Market Risk	35
Item 4.  Controls and Procedures	36
Part II.  Other Information
Item 1.  Legal Proceedings	36
Item 1A.  Risk Factors	36
Item 2.  Unregistered Sales of Equity Securities, Use of Proceeds and Issuer Purchases of Equity Securities	36
Item 3.  Defaults Upon Senior Securities	36
Item 4.  Mine Safety Disclosures	37
Item 5.  Other Information	37
Item 6.  Exhibits	37

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Part I.  Financial Information

Item 1.  Financial Statements

Callon Petroleum Company

Consolidated Balance Sheets

(In thousands, except par and share amounts)

(Unaudited)

	September 30, 2023	December 31, 2022*
ASSETS
Current assets:
Cash and cash equivalents	$3,456	$3,395
Accounts receivable, net	262,394	237,128
Fair value of derivatives	1,196	21,332
Other current assets	29,665	35,783
Total current assets	296,711	297,638
Oil and natural gas properties, successful efforts accounting method:
Proved properties, net	4,815,776	4,851,529
Unproved properties	1,287,019	1,225,768
Total oil and natural gas properties, net	6,102,795	6,077,297
Other property and equipment, net	26,398	26,152
Deferred income taxes	199,734	—
Deferred financing costs	14,235	18,822
Fair value of derivatives	21,742	454
Other assets, net	66,908	68,106
Total assets	$6,728,523	$6,488,469
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable and accrued liabilities	$585,529	$536,233
Fair value of derivatives	61,189	16,197
Other current liabilities	103,077	150,384
Total current liabilities	749,795	702,814
Long-term debt	1,948,619	2,241,295
Asset retirement obligations	41,290	53,892
Fair value of derivatives	44,807	13,415
Other long-term liabilities	82,954	51,272
Total liabilities	2,867,465	3,062,688
Commitments and contingencies
Stockholders’ equity:
Common stock, $0.01 par value, 130,000,000 shares authorized; 67,770,721 and 61,621,518 shares outstanding, respectively	678	616
Capital in excess of par value	4,225,183	4,022,194
Accumulated deficit	(364,803)	(597,029)
Total stockholders’ equity	3,861,058	3,425,781
Total liabilities and stockholders’ equity	$6,728,523	$6,488,469

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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

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Callon Petroleum Company

Consolidated Statements of Operations

(In thousands, except per share amounts)

(Unaudited)

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022*	2023	2022*
Operating Revenues:
Oil	$438,665	$575,852	$1,269,996	$1,748,913
Natural gas	25,045	81,018	63,054	189,907
Natural gas liquids	46,489	67,548	130,488	210,696
Sales of purchased oil and gas	109,099	111,459	278,089	377,199
Total operating revenues	619,298	835,877	1,741,627	2,526,715
Operating Expenses:
Lease operating	73,525	76,121	225,415	216,389
Production and ad valorem taxes	30,592	43,290	88,019	125,841
Gathering, transportation and processing	27,255	27,575	80,570	71,617
Exploration	3,588	2,942	7,702	7,237
Cost of purchased oil and gas	111,118	111,439	285,947	378,107
Depreciation, depletion and amortization	138,598	129,895	391,911	359,494
Impairment of oil and gas properties	—	—	406,898	—
Gain on sale of oil and gas properties	(20,570)	—	(20,570)	—
General and administrative	29,339	24,253	86,905	71,485
Merger, integration and transaction	4,925	—	6,468	769
Total operating expenses	398,370	415,515	1,559,265	1,230,939
Income From Operations	220,928	420,362	182,362	1,295,776
Other (Income) Expenses:
Interest expense	43,149	46,929	136,694	141,020
(Gain) loss on derivative contracts	55,804	(134,850)	24,218	305,098
(Gain) loss on extinguishment of debt	(1,238)	—	(1,238)	42,417
Other (income) expense	3,220	2,861	(3,140)	3,130
Total other (income) expense	100,935	(85,060)	156,534	491,665
Income Before Income Taxes	119,993	505,422	25,828	804,111
Income tax benefit (expense)	(509)	(3,383)	206,398	(6,536)
Net Income	$119,484	$502,039	$232,226	$797,575
Net Income Per Common Share:
Basic	$1.76	$8.14	$3.64	$12.94
Diluted	$1.75	$8.11	$3.63	$12.88
Weighted Average Common Shares Outstanding:
Basic	67,931	61,703	63,827	61,624
Diluted	68,083	61,870	64,016	61,927

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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

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Callon Petroleum Company

Consolidated Statements of Stockholders’ Equity

(In thousands)

(Unaudited)

	Common		Capital in		Total
	Stock		Excess	Accumulated	Stockholders’
	Shares	$	of Par	Deficit	Equity
Balance at December 31, 2022*	61,622	$616	$4,022,194	($597,029)	$3,425,781
Net income	—	—	—	220,638	220,638
Restricted stock units	3	—	3,339	—	3,339
Balance at March 31, 2023	61,625	$616	$4,025,533	($376,391)	$3,649,758
Net loss	—	—	—	(107,896)	(107,896)
Restricted stock units	263	3	807	—	810
Balance at June 30, 2023	61,888	$619	$4,026,340	($484,287)	$3,542,672
Net income	—	—	—	119,484	119,484
Restricted stock units	2	—	3,881	—	3,881
Common stock issued for Percussion Acquisition	6,267	63	209,937	—	210,000
Repurchase and retirement of common stock	(386)	(4)	(14,975)	—	(14,979)
Balance at September 30, 2023	67,771	$678	$4,225,183	($364,803)	$3,861,058

	Common		Capital in		Total
	Stock		Excess	Accumulated	Stockholders’
	Shares	$	of Par	Deficit	Equity
Previously reported at December 31, 2021	61,371	$614	$4,012,358	($2,147,204)	$1,865,768
Effect of change in accounting principle	—	—	—	530,732	530,732
Balance at December 31, 2021 as recast*	61,371	$614	$4,012,358	($1,616,472)	$2,396,500
Net loss	—	—	—	(7,715)	(7,715)
Restricted stock units	6	—	2,790	—	2,790
Common stock issued for Primexx Acquisition	117	1	6,294	—	6,295
Balance at March 31, 2022*	61,494	$615	$4,021,442	($1,624,187)	$2,397,870
Net income	—	—	—	303,251	303,251
Restricted stock units	244	2	(1,901)	—	(1,899)
Common stock issued for Primexx Acquisition	(22)	—	(1,363)	—	(1,363)
Balance at June 30, 2022*	61,716	$617	$4,018,178	($1,320,936)	$2,697,859
Net income	—	—	—	502,039	502,039
Restricted stock units	1	—	3,893	—	3,893
Common stock issued for Primexx Acquisition	(110)	(1)	(3,830)	—	(3,831)
Balance at September 30, 2022*	61,607	$616	$4,018,241	($818,897)	$3,199,960

*Financial information for prior periods has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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

5

Callon Petroleum Company

Consolidated Statements of Cash Flows

(In thousands)

(Unaudited)

	Nine Months Ended September 30,
Cash flows from operating activities:	2023	2022*
Net income	$232,226	$797,575
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	391,911	359,494
Impairment of oil and gas properties	406,898	—
Amortization of non-cash debt related items, net	7,979	9,680
Deferred income tax (benefit) expense	(206,041)	1,110
(Gain) loss on derivative contracts	24,218	305,098
Cash received (paid) for commodity derivative settlements, net	13,274	(433,518)
Gain on extinguishment of debt	(1,238)	42,417
Gain on sale of oil and gas properties	(20,570)	—
Non-cash expense related to share-based awards	9,524	4,427
Other, net	4,563	8,704
Changes in current assets and liabilities:
Accounts receivable	14,219	(52,423)
Other current assets	(13,178)	(12,229)
Accounts payable and accrued liabilities	(69,522)	(8,649)
Net cash provided by operating activities	794,263	1,021,686
Cash flows from investing activities:
Capital expenditures	(751,004)	(648,149)
Acquisition of oil and gas properties	(278,434)	(17,006)
Proceeds from sales of assets	551,446	9,313
Cash paid for settlement of contingent consideration arrangement	—	(19,171)
Other, net	(2,850)	13,497
Net cash used in investing activities	(480,842)	(661,516)
Cash flows from financing activities:
Borrowings on credit facility	2,629,500	2,535,000
Payments on credit facility	(2,736,500)	(2,684,000)
Issuance of 7.5% Senior Notes due 2030	—	600,000
Redemption of 8.25% Senior Notes due 2025	(187,238)	—
Redemption of 6.125% Senior Notes due 2024	—	(467,287)
Redemption of 9.0% Second Lien Senior Secured Notes due 2025	—	(339,507)
Payment of deferred financing costs	(560)	(11,623)
Cash paid to repurchase common stock	(14,980)	—
Other, net	(3,582)	1,715
Net cash used in financing activities	(313,360)	(365,702)
Net change in cash and cash equivalents	61	(5,532)
Balance, beginning of period	3,395	9,882
Balance, end of period	$3,456	$4,350

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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

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Index to the Notes to the Consolidated Financial Statements

1.	Description of Business	10.	Fair Value Measurements
2.	Summary of Significant Accounting Policies	11.	Income Taxes
3.	Change in Accounting Principle	12.	Share-Based Compensation
4.	Revenue Recognition	13.	Stockholders’ Equity
5.	Acquisitions and Divestitures	14.	Accounts Receivable, Net
6.	Property and Equipment, Net	15.	Accounts Payable and Accrued Liabilities
7.	Earnings Per Share	16.	Supplemental Cash Flow
8.	Borrowings	17.	Subsequent Events
9.	Derivative Instruments and Hedging Activities

Note 1 — Description of Business

Callon Petroleum Company is an independent oil and natural gas company focused on the acquisition, exploration and sustainable development of high-quality assets in the Permian Basin in West Texas. As used herein, the “Company,” “Callon,” “we,” “us,” and “our” refer to Callon Petroleum Company and its predecessors and subsidiaries unless the context requires otherwise.

Note 2 — Summary of Significant Accounting Policies

Basis of Presentation

The accompanying unaudited interim consolidated financial statements include the accounts of the Company after elimination of intercompany transactions and balances. These financial statements have been prepared pursuant to the rules and regulations of the SEC and therefore do not include all disclosures required for financial statements prepared in conformity with GAAP. In the opinion of management, these financial statements reflect all normal, recurring adjustments and accruals considered necessary to present fairly, in all material respects, the Company’s interim financial position, results of operations and cash flows. However, the results of operations for the periods presented are not necessarily indicative of the results of operations that may be expected for the full year. Certain reclassifications have been made to prior period amounts to conform to the current period presentation. Such reclassifications did not have a material impact on prior period financial statements.

Significant Accounting Policies

The Company’s significant accounting policies are described in “Note 2 — Summary of Significant Accounting Policies” of the Notes to Consolidated Financial Statements in its 2022 Annual Report and are supplemented by the notes included in this Form 10-Q. The financial statements and related notes included in this Form 10-Q should be read in conjunction with the Company’s 2022 Annual Report.

Recast Financial Information for Change in Accounting Principle

In the first quarter of 2023, the Company voluntarily changed its method of accounting for its oil and gas exploration and development activities from the full cost method to the successful efforts method of accounting. Accordingly, the financial information for prior periods has been recast to reflect retrospective application of the successful efforts method, as prescribed by the FASB Accounting Standards Codification (“ASC”) 932 “Extractive Activities — Oil and Gas.” Although the full cost method of accounting continues to be an accepted alternative, the successful efforts method of accounting is the generally preferred method of the SEC and, because it is more widely used in the industry, the Company expects the change to improve the comparability of its financial statements to its peers. The Company also believes the successful efforts method provides a more representational depiction of assets and operating results and provides for its investments in oil and natural gas properties to be assessed for impairment in accordance with ASC Topic 360 “Property Plant and Equipment,” rather than valuations based on prices and costs prescribed under the full cost method as of the balance sheet date. As required by ASC 250 “Accounting Changes and Error Corrections,” the Company has presented the accumulated effect of the change in accounting principle as a change in the beginning balance of retained earnings (accumulated deficit) of the earliest period presented in the consolidated financial statements. For detailed information regarding the effects of the change to the successful efforts method, see “Note 3 — Change in Accounting Principle.”

Oil and Natural Gas Properties

Proved Oil and Natural Gas Properties. The Company follows the successful efforts method of accounting for its oil and gas properties. Under this method, drilling and completion costs, including lease and well equipment, intangible development costs, and operational support facilities in the field, associated with development wells are capitalized to proved oil and gas properties and are depleted on an asset group basis (properties aggregated based on geographical and geological characteristics) using the units-of-production method based on estimated proved developed oil and gas reserves. The calculation of depletion expense takes into consideration estimated asset retirement costs, net of estimated salvage values.

Proved oil and gas properties are assessed for impairment on an asset group basis whenever events and circumstances indicate that there could be a possible decline in the recoverability of the net book value of such property. The Company estimates the expected

7

future net cash flows of its proved oil and gas properties and compares these undiscounted cash flows to the net book value of the proved oil and gas properties to determine if the net book value is recoverable. If the net book value exceeds the estimated undiscounted future net cash flows, the Company will recognize an impairment to reduce the net book value of the proved oil and gas properties to fair value. The factors used to determine fair value include, but are not limited to, estimates of reserves, future commodity prices, future production estimates, estimated future development costs and operating costs, and discount rates, which are based on a weighted average cost of capital. See “Note 5 — Acquisitions and Divestitures” for details of the impairment recorded in the second quarter of 2023 associated with the sale of all the Company’s interests of Callon (Eagle Ford) LLC to Ridgemar Energy Operating, LLC.

The partial sale of a proved property within an existing asset group is accounted for as a normal retirement and no net gain or loss on divestiture is recognized as long as the treatment does not significantly alter the units-of-production depletion rate. The sale of a partial interest in an individual proved property is accounted for as a recovery of cost. A net gain or loss on divestiture is recognized in the consolidated statements of operations for all other sales of proved properties.

Unproved Oil and Natural Gas Properties. Unproved oil and gas properties consist of costs incurred in obtaining a mineral interest or a right in a property such as a lease, in addition to broker fees, recording fees and other similar costs. Leasehold costs are classified as unproved until proved reserves are discovered on or otherwise attributed to the property, at which time the related unproved oil and gas property costs are reclassified to proved oil and gas properties and depleted on an asset group basis using the units-of-production method based on estimated total proved oil and gas reserves.

The Company evaluates significant unproved oil and gas property costs for impairment based on remaining lease term, drilling results, reservoir performance, seismic interpretation or changes in future plans to develop acreage. Unproved oil and gas properties that are not individually significant are aggregated by asset group, and the portion of such costs estimated to be nonproductive prior to lease expiration is amortized over the average holding period. The estimate of what could be nonproductive is based on the Company’s historical experience or other information, including current drilling plans and existing geological data. Impairment and amortization of unproved oil and gas properties are recognized as “Impairment of oil and gas properties” in the consolidated statements of operations.

Exploratory. Exploratory costs, including personnel and other internal costs, geological and geophysical expenses and delay rentals for oil and gas leases, are expensed as incurred. Exploratory well costs are initially capitalized pending the determination of whether proved reserves have been discovered. If proved reserves are discovered, exploratory well costs are capitalized as proved oil and gas properties. If proved reserves are not found, exploratory well costs are expensed as dry holes. The application of the successful efforts method of accounting requires management’s judgment to determine the proper designation of wells as either development or exploratory, which will ultimately determine the proper accounting treatment of costs of dry holes.

Capitalized Interest. The Company capitalizes interest on expenditures made in connection with exploration and development projects that meet certain thresholds and are not subject to current amortization. For projects that meet these thresholds, interest is capitalized only for the period that activities are in process to bring the projects to their intended use. Capitalized interest cannot exceed interest expense for the period capitalized. During both the three and nine months ended September 30, 2023 and 2022, the Company did not have any projects that met the thresholds and, therefore, had no capitalized interest.

Share Repurchase Program

The Company repurchases shares of its common stock from time to time under a program authorized by the Board of Directors. The Company retires shares acquired through share repurchases and returns those shares to the status of authorized but unissued. The repurchased and retired shares are recorded as a reduction to “Common stock” and “Capital in excess of par value” in the consolidated balance sheets. See “Note 13 — Stockholders’ Equity” for further discussion.

Recently Issued Accounting Standards

As of September 30, 2023, and through the filing of this report, no new accounting standards have been issued and not yet adopted that are applicable to the Company and that would have a material effect on the Company’s unaudited interim consolidated financial statements and related disclosures.

Subsequent Events

The Company evaluates subsequent events through the date the financial statements are issued. See “Note 17 — Subsequent Events” for further discussion.

Note 3 — Change in Accounting Principle

In the first quarter of 2023, the Company voluntarily changed its method of accounting for oil and natural gas exploration and development activities from the full cost method to the successful efforts method. Accordingly, financial information for prior periods has been recast to reflect retrospective application of the successful efforts method. In general, under successful efforts, exploration costs such as exploratory dry holes, exploratory geophysical and geological costs, delay rentals, unproved leasehold impairments and

8

exploration overhead are expensed as incurred as opposed to being capitalized under the full cost method of accounting. The successful efforts method also provides for the assessment of potential proved oil and gas property impairments by comparing the net book value of proved oil and gas properties to associated estimated undiscounted future net cash flows. If the net book value exceeds the estimated undiscounted future net cash flows, an impairment is recorded to reduce the net book value to fair value. Under the full cost method of accounting, an impairment would be required if the net book value of oil and natural gas properties exceeds a full cost ceiling using an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous 12 months. In addition, gains or losses, if applicable, are recognized more frequently on the divestitures of oil and gas properties under the successful efforts method, as opposed to an adjustment to the net book value of the oil and gas properties under the full cost method.

The “Impairment of oil and gas properties” and “Gain on sale of oil and gas properties” line items presented in the tables below are in connection with the sale of all of the Company’s interests of Callon (Eagle Ford) LLC to Ridgemar Energy Operating, LLC. See “Note 5 — Acquisitions and Divestitures” for additional details.

The following tables present the effects of the change to the successful efforts method in the consolidated balance sheets:

	As of September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Oil and natural gas properties:
Proved properties	$11,191,350	($1,947,545)	$9,243,805
Accumulated depreciation, depletion, amortization and impairments	(6,734,174)	2,306,145	(4,428,029)
Unproved properties	1,807,300	(520,281)	1,287,019
Total oil and gas properties, net	6,264,476	(161,681)	6,102,795
Deferred income taxes	170,001	29,733	199,734
Total assets	$6,860,471	($131,948)	$6,728,523
Stockholders’ equity:
Accumulated deficit	(232,855)	(131,948)	(364,803)
Total stockholders' equity	3,993,006	(131,948)	3,861,058
Total liabilities and stockholders' equity	$6,860,471	($131,948)	$6,728,523

	As of December 31, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Oil and natural gas properties:
Proved properties	$10,367,478	($1,099,343)	$9,268,135
Accumulated depreciation, depletion, amortization and impairments	(6,343,875)	1,927,269	(4,416,606)
Unproved properties	1,711,306	(485,538)	1,225,768
Total oil and gas properties, net	5,734,909	342,388	6,077,297
Total assets	$6,146,081	$342,388	$6,488,469
Deferred income taxes (1)	4,279	2,029	6,308
Stockholders’ equity:
Accumulated deficit	(937,388)	340,359	(597,029)
Total stockholders' equity	3,085,422	340,359	3,425,781
Total liabilities and stockholders' equity	$6,146,081	$342,388	$6,488,469

(1)    Included in “Other long-term liabilities” in the consolidated balance sheets.

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The following tables present the effects of the change to the successful efforts method in the consolidated statements of operations:

	Three Months Ended September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands, except per share amounts)
Operating Expenses:
Exploration	$—	$3,588	$3,588
Depreciation, depletion and amortization	138,313	285	138,598
Gain on sale of oil and gas properties	—	(20,570)	(20,570)
General and administrative	22,016	7,323	29,339
Income From Operations	211,554	9,374	220,928
Other Expenses:
Interest expense	14,145	29,004	43,149
Income Before Income Taxes	139,623	(19,630)	119,993
Income tax benefit (expense)	10,663	(11,172)	(509)
Net Income	$150,286	($30,802)	$119,484
Net Income Per Common Share:
Basic	$2.21		$1.76
Diluted	$2.21		$1.75

	Three Months Ended September 30, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands, except per share amounts)
Operating Expenses:
Exploration	$—	$2,942	$2,942
Depreciation, depletion and amortization	122,833	7,062	129,895
General and administrative	14,022	10,231	24,253
Income From Operations	440,597	(20,235)	420,362
Other Expenses:
Interest expense	19,468	27,461	46,929
Income Before Income Taxes	553,118	(47,696)	505,422
Income tax expense	(3,515)	132	(3,383)
Net Income	$549,603	($47,564)	$502,039
Net Income Per Common Share:
Basic	$8.91		$8.14
Diluted	$8.88		$8.11

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	Nine Months Ended September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands, except per share amounts)
Operating Expenses:
Exploration	$—	$7,702	$7,702
Depreciation, depletion and amortization	396,348	(4,437)	391,911
Impairment of oil and gas properties	—	406,898	406,898
Gain on sale of oil and gas properties	—	(20,570)	(20,570)
General and administrative	56,305	30,600	86,905
Income From Operations	602,555	(420,193)	182,362
Other Expenses:
Interest expense	52,818	83,876	136,694
Income Before Income Taxes	529,897	(504,069)	25,828
Income tax benefit	174,636	31,762	206,398
Net Income	$704,533	($472,307)	$232,226
Net Income Per Common Share:
Basic	$11.04		$3.64
Diluted	$11.01		$3.63

	Nine Months Ended September 30, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands, except per share amounts)
Operating Expenses:
Exploration	$—	$7,237	$7,237
Depreciation, depletion and amortization	335,221	24,273	359,494
General and administrative	42,052	29,433	71,485
Income From Operations	1,356,719	(60,943)	1,295,776
Other Expenses:
Interest expense	61,717	79,303	141,020
Income Before Income Taxes	944,357	(140,246)	804,111
Income tax expense	(7,008)	472	(6,536)
Net Income	$937,349	($139,774)	$797,575
Net Income Per Common Share:
Basic	$15.21		$12.94
Diluted	$15.14		$12.88

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The following tables present the effects of the change to the successful efforts method in the consolidated statements of cash flows:

	Nine Months Ended September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Cash flows from operating activities:
Net income	$704,533	($472,307)	$232,226
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	396,348	(4,437)	391,911
Impairment of oil and gas properties	—	406,898	406,898
Amortization of non-cash debt related items, net	3,064	4,915	7,979
Deferred income tax benefit	(174,279)	(31,762)	(206,041)
Gain on sale of oil and gas properties	—	(20,570)	(20,570)
Non-cash expense related to share-based awards	3,848	5,676	9,524
Net cash provided by operating activities	905,850	(111,587)	794,263
Cash flows from investing activities:
Capital expenditures	(854,889)	103,885	(751,004)
Acquisition of oil and gas properties	(286,136)	7,702	(278,434)
Net cash used in investing activities	(592,429)	111,587	(480,842)
Net change in cash and cash equivalents	61	—	61
Balance, beginning of period	3,395	—	3,395
Balance, end of period	$3,456	$—	$3,456

	Nine Months Ended September 30, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Cash flows from operating activities:
Net income	$937,349	($139,774)	$797,575
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	335,221	24,273	359,494
Amortization of non-cash debt related items, net	4,263	5,417	9,680
Deferred income tax expense	1,626	(516)	1,110
Non-cash expense related to share-based awards	1,055	3,372	4,427
Changes in current assets and liabilities:
Accounts payable and accrued liabilities	(8,693)	44	(8,649)
Net cash provided by operating activities	1,128,870	(107,184)	1,021,686
Cash flows from investing activities:
Capital expenditures	(754,225)	106,076	(648,149)
Acquisition of oil and gas properties	(18,114)	1,108	(17,006)
Net cash used in investing activities	(768,700)	107,184	(661,516)
Net change in cash and cash equivalents	(5,532)	—	(5,532)
Balance, beginning of period	9,882	—	9,882
Balance, end of period	$4,350	$—	$4,350

The following tables present the effects of the change to the successful efforts method in the consolidated statements of stockholders’ equity:

	As of September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Accumulated deficit	($232,855)	($131,948)	($364,803)
Total stockholders’ equity	$3,993,006	($131,948)	$3,861,058

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	As of December 31, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Accumulated deficit	($937,388)	$340,359	($597,029)
Total stockholders’ equity	$3,085,422	$340,359	$3,425,781

Note 4 — Revenue Recognition

Revenue from Contracts with Customers

The Company recognizes oil, natural gas, and NGL production revenue at the point in time when control of the product transfers to the purchaser, which differs depending on the applicable contractual terms. Transfer of control also drives the presentation of gathering, transportation and processing expenses in the consolidated statements of operations. See “Note 3 — Revenue Recognition” of the Notes to Consolidated Financial Statements in the 2022 Annual Report for more information regarding the types of contracts under which oil, natural gas, and NGL production revenue is generated.

Oil and Gas Purchase and Sale Arrangements

The Company proactively evaluates development plans and looks to enter into pipeline transportation contracts to mitigate market exposures and help ensure certainty of flow for its oil and gas production, in some cases multiple years in advance of development. Additionally, as the Company looks to optimize its operations and reduce exposures, in certain instances, the Company purchases oil and gas from third parties which is utilized to fulfill portions of its pipeline commitments. Sales of purchased oil and gas represent revenues the Company receives from sales of commodities purchased from a third party. The Company recognizes these revenues and the purchase of the third-party commodities, as well as any costs associated with the purchase, on a gross basis, as the Company acts as a principal in these transactions by assuming control of the purchased commodity before it is transferred to the customer.

Accounts Receivable from Revenues from Contracts with Customers

Net accounts receivable include amounts billed and currently due from revenues from contracts with customers of our oil and natural gas production, which had a balance at September 30, 2023 and December 31, 2022 of $169.3 million and $174.1 million, respectively, and are presented in “Accounts receivable, net” in the consolidated balance sheets.

Prior Period Performance Obligations

The Company records revenue in the month production is delivered to the purchaser. However, settlement statements for sales may not be received for 30 to 90 days after the date production is delivered, and as a result, the Company is required to estimate the amount of production delivered to the purchaser and the price that will be received for the sale of the product. The Company records the differences between estimates and the actual amounts received for product sales in the month that payment is received from the purchaser. The Company has existing internal controls for its revenue estimation process and related accruals, and any identified differences between its revenue estimates and actual revenue received historically have not been significant.

Note 5 — Acquisitions and Divestitures

Eagle Ford Divestiture

On May 3, 2023, the Company entered into an agreement with Ridgemar Energy Operating, LLC (“Ridgemar”) for the sale of all its oil and gas properties in the Eagle Ford (the “Eagle Ford Divestiture”) for consideration of $655.0 million in cash, subject to customary purchase price adjustments, as well as contingent consideration where the Company could receive up to $45.0 million if the WTI price of oil exceeds certain thresholds in 2024 (“Contingent Eagle Ford Consideration”). See “Note 9 — Derivative Instruments and Hedging Activities” for further discussion of the Contingent Eagle Ford Consideration. Upon signing, Ridgemar paid approximately $49.1 million as a deposit into a third-party escrow account. The transaction was structured as the acquisition by Ridgemar of 100% of the limited liability company interests of the Company’s wholly owned subsidiary, Callon (Eagle Ford) LLC.

During the second quarter of 2023, the Company classified the assets and liabilities associated with the Eagle Ford Divestiture as held for sale, and recorded an impairment of $406.9 million against properties associated with the Eagle Ford Divestiture as the fair value less cost to sell was less than the carrying amount of the net assets. On July 3, 2023, the Company closed the Eagle Ford Divestiture. The Eagle Ford Divestiture has an adjusted purchase price of approximately $549.3 million in cash, inclusive of the deposit paid at signing, subject to customary post-closing purchase price adjustments. As a result, the Company recorded a gain on sale of assets of $20.6 million.

Percussion Acquisition

On May 3, 2023, the Company entered into an agreement (the “Percussion Agreement”) with Percussion Petroleum Management II, LLC (“Percussion”) for the purchase of its oil and gas properties in the Delaware Basin (the “Percussion Acquisition”) for

13

consideration of $475.0 million, which consisted of $255.0 million in cash, inclusive of the repayment of Percussion’s indebtedness of approximately $220.0 million, and $210.0 million of shares of the Company’s common stock, subject to customary purchase price adjustments. Upon signing, the Company paid $36.0 million as a deposit into a third-party escrow account. The transaction was structured as the acquisition by Callon Petroleum Operating Company of 100% of the limited liability company interests of Percussion’s wholly owned subsidiary, Percussion Petroleum Operating II, LLC (“Percussion Operating”).

On July 3, 2023, the Company closed the Percussion Acquisition for an adjusted purchase price of approximately $248.5 million in cash, inclusive of the deposit paid at signing and the repayment of Percussion Operating’s indebtedness of approximately $220.0 million, and approximately 6.3 million shares of the Company’s common stock for total consideration of $458.5 million, subject to customary post-closing purchase price adjustments. The Company funded the cash portion of the total consideration with proceeds from the Eagle Ford Divestiture. Additionally, the Company assumed Percussion Operating’s (as defined below) existing hedges and transportation contract liabilities, and could have to pay up to $62.5 million if the WTI price of oil exceeds certain thresholds in 2023, 2024, and 2025 (“Percussion Earn-Out Obligation”).

The Percussion Acquisition was accounted for as a business combination; therefore, the purchase price was allocated to the assets acquired and the liabilities assumed based on their estimated acquisition date fair values with information available at that time. A combination of a discounted cash flow model and market data was used by a third-party specialist in determining the fair value of the oil and gas properties. Significant inputs into the calculation included future commodity prices, estimated volumes of oil and gas reserves, expectations for timing and amount of future development and operating costs, future plugging and abandonment costs and a risk adjusted discount rate. Certain data necessary to complete the purchase price allocation is not yet available. The Company expects to complete the purchase price allocation during the 12-month period following the acquisition date.

The following table sets forth the Company’s preliminary allocation of the total estimated consideration of $458.5 million to the assets acquired and liabilities assumed as of the acquisition date.

	Preliminary Purchase Price Allocation
	(In thousands)
Assets:
Accounts receivable, net	$30,135
Proved properties, net	491,367
Unproved properties	52,590
Total assets acquired	$574,092
Liabilities:
Accounts payable and accrued liabilities	$42,585
Fair value of derivatives - current	20,660
Other current liabilities	11,471
Asset retirement obligations	2,323
Fair value of derivatives - long-term	27,979
Other long-term liabilities	10,619
Total liabilities assumed	$115,637
Total consideration	$458,455

Approximately $57.8 million of revenues and $16.3 million of direct operating expenses attributed to the assets acquired in the Percussion Acquisition are included in the Company’s consolidated statements of operations for the period from the closing date on July 3, 2023 through September 30, 2023.

Pro Forma Operating Results (Unaudited). The following unaudited pro forma combined condensed financial data for the three and nine months ended September 30, 2023 and 2022 was derived from the historical financial statements of the Company and gives effect to the Percussion Acquisition, as if it had occurred on January 1, 2022. The below information reflects pro forma adjustments for the issuance of the Company’s common stock, as well as pro forma adjustments based on available information and certain assumptions that the Company believes provide a reasonable basis for reflecting the significant pro forma effects directly attributable to the Percussion Acquisition.

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The pro forma consolidated statements of operations data has been included for comparative purposes only and is not necessarily indicative of the results that might have occurred had the Percussion Acquisition taken place on January 1, 2022 and is not intended to be a projection of future results.

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022*	2023	2022*
	(In thousands, except per share amounts)
Revenues	$619,298	$928,218	$1,879,442	$2,815,342
Income from operations	220,928	480,459	252,809	1,490,205
Net income	119,484	708,355	360,850	856,610
Basic earnings per common share	$1.76	$10.42	$5.65	$12.62
Diluted earnings per common share	$1.75	$10.40	$5.64	$12.56

Note 6 — Property and Equipment, Net

As of September 30, 2023 and December 31, 2022, total property and equipment, net consisted of the following:

	September 30, 2023	December 31, 2022*
Oil and natural gas properties, successful efforts accounting method	(In thousands)
Proved properties	$9,243,805	$9,268,135
Accumulated depreciation, depletion, amortization and impairments	(4,428,029)	(4,416,606)
Proved properties, net	4,815,776	4,851,529
Unproved properties	1,287,019	1,225,768
Total oil and natural gas properties, net	$6,102,795	$6,077,297
Other property and equipment	$40,243	$40,530
Accumulated depreciation	(13,845)	(14,378)
Other property and equipment, net	$26,398	$26,152

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

Note 7 — Earnings Per Share

Basic earnings per share is computed by dividing net income by the weighted average number of shares outstanding for the periods presented. The calculation of diluted earnings per share includes the potential dilutive impact of non-vested restricted stock units outstanding during the periods presented, as calculated using the treasury stock method, unless their effect is anti-dilutive.

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The following table sets forth the computation of basic and diluted earnings per share:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022*	2023	2022*
	(In thousands, except per share amounts)
Net Income	$119,484	$502,039	$232,226	$797,575
Basic weighted average common shares outstanding	67,931	61,703	63,827	61,624
Dilutive impact of restricted stock units	152	167	189	303
Diluted weighted average common shares outstanding	68,083	61,870	64,016	61,927
Net Income Per Common Share
Basic	$1.76	$8.14	$3.64	$12.94
Diluted	$1.75	$8.11	$3.63	$12.88
Restricted stock units (1)	54	100	75	28
Warrants (1)	481	481	481	416

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

(1)    Shares excluded from the diluted earnings per share calculation because their effect would be anti-dilutive.

Note 8 — Borrowings

The Company’s borrowings consisted of the following:

	September 30, 2023	December 31, 2022
	(In thousands)
8.25% Senior Notes due 2025	$—	$187,238
6.375% Senior Notes due 2026	320,783	320,783
Senior Secured Revolving Credit Facility due 2027	396,000	503,000
8.0% Senior Notes due 2028	650,000	650,000
7.5% Senior Notes due 2030	600,000	600,000
Total principal outstanding	1,966,783	2,261,021
Unamortized premium on 8.25% Senior Notes	—	1,715
Unamortized deferred financing costs for Senior Notes	(18,164)	(21,441)
Long-term debt (1)	$1,948,619	$2,241,295

(1)    Excludes unamortized deferred financing costs related to the Company’s senior secured revolving credit facility of $14.2 million and $18.8 million as of September 30, 2023 and December 31, 2022, respectively, which are classified in “Deferred financing costs” in the consolidated balance sheets.

Senior Secured Revolving Credit Facility

The Company has a senior secured revolving credit facility with a syndicate of lenders (the “Credit Facility”) that, as of September 30, 2023, had a maximum credit amount of $5.0 billion, a borrowing base of $2.0 billion and an elected commitment amount of $1.5 billion, with borrowings outstanding of $396.0 million at a weighted-average interest rate of 7.50%, and letters of credit outstanding of $21.4 million. The credit agreement governing the Credit Facility (the “Credit Agreement”) provides for interest-only payments until October 19, 2027 when the Credit Agreement matures and any outstanding borrowings are due.

Borrowings outstanding under the Credit Agreement bear interest at the Company’s option at either (i) a base rate for a base rate loan plus a margin between 0.75% to 1.75%, where the base rate is defined as the greatest of the prime rate, the federal funds rate plus 0.50%, and the SOFR plus 0.1% (“Adjusted SOFR”) for a one month period plus 1.00%, or (ii) an Adjusted SOFR plus a margin between 1.75% to 2.75%. The Company also incurs commitment fees at rates ranging between 0.375% to 0.500% on the unused portion of lender commitments, which are included in “Interest expense” in the consolidated statements of operations.

The borrowing base under the Credit Agreement is subject to regular redeterminations in the spring and fall of each year, as well as special redeterminations described in the Credit Agreement, which in each case may reduce the amount of the borrowing base. On October 31, 2023, as part of the Company’s fall 2023 redetermination, the borrowing base of $2.0 billion and elected commitment amount of $1.5 billion were reaffirmed.

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Redemption of 8.25% Senior Notes due 2025

On August 2, 2023, the Company used borrowings under the Credit Facility to redeem all $187.2 million of its outstanding 8.25% Senior Notes due 2025 (“8.25% Senior Notes”). The Company recognized a gain on extinguishment of debt of approximately $1.2 million in its consolidated statements of operations, which primarily related to the remaining unamortized premium.

Covenants

The Credit Agreement and the indentures governing the 6.375% Senior Notes due 2026, the 8.0% Senior Notes due 2028, and the 7.5% Senior Notes due 2030 (collectively, the “Senior Notes”) limit the Company and certain of its subsidiaries with respect to the amount of additional indebtedness, liens, dividends and other payments to shareholders, repurchases or redemptions of the Company’s common stock, redemptions of senior notes, investments, acquisitions, mergers, asset dispositions, transactions with affiliates, hedging transactions and other matters, along with maintenance of certain financial ratios.

Under the Credit Agreement, the Company must maintain the following financial covenants determined as of the last day of the quarter: (1) a Leverage Ratio (as defined in the Credit Agreement) of no more than 3.50 to 1.00 and (2) a Current Ratio (as defined in the Credit Agreement) of not less than 1.00 to 1.00. The Company was in compliance with these covenants at September 30, 2023.

The Credit Agreement and indentures are subject to customary events of default. If an event of default occurs and is continuing, the holders or lenders may elect to accelerate amounts due (except in the case of a bankruptcy event of default, in which case such amounts will automatically become due and payable).

Note 9 — Derivative Instruments and Hedging Activities

Objectives and Strategies for Using Derivative Instruments

The Company is exposed to fluctuations in oil, natural gas and NGL prices received for its production. Consequently, the Company believes it is prudent to manage the variability in cash flows on a portion of its oil, natural gas and NGL production. The Company utilizes a mix of collars, swaps, put and call options, and basis differential swaps to manage fluctuations in cash flows resulting from changes in commodity prices. The Company does not use these instruments for speculative or trading purposes.

Counterparty Risk and Offsetting

The Company typically has numerous commodity derivative instruments outstanding with a counterparty that were executed at various dates, for various contract types, commodities and time periods. This often results in both commodity derivative asset and liability positions with that counterparty. The Company nets its commodity derivative instrument fair values executed with the same counterparty to a single asset or liability pursuant to International Swap Dealers Association Master Agreements, which provide for net settlement over the term of the contract and in the event of default or termination of the contract. In general, if a party to a derivative transaction incurs an event of default, as defined in the applicable agreement, the other party will have the right to demand the posting of collateral, demand a cash payment transfer or terminate the arrangement.

The Company strives to minimize its credit exposure to any individual counterparty and, as such, the Company has outstanding commodity derivative instruments with nine counterparties as of September 30, 2023. All of the counterparties to the Company’s commodity derivative instruments are also lenders under the Company’s Credit Facility. Therefore, each of the Company’s counterparties allow the Company to satisfy any need for margin obligations associated with commodity derivative instruments where the Company is in a net liability position with the collateral securing the Credit Facility, thus eliminating the need for independent collateral posting.

Because each of the Company’s counterparties has an investment grade credit rating, the Company believes it does not have significant credit risk and accordingly does not currently require its counterparties to post collateral to support the net asset positions of its commodity derivative instruments. Although the Company does not currently anticipate nonperformance from its counterparties, it continually monitors the credit ratings of each counterparty.

While the Company monitors counterparty creditworthiness on an ongoing basis, it cannot predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, the Company may be limited in its ability to mitigate an increase in counterparty credit risk. Should one of these counterparties not perform, the Company may not realize the benefit of some of its derivative instruments under lower commodity prices while continuing to be obligated under higher commodity price contracts subject to any right of offset under the agreements. Counterparty credit risk is considered when determining the fair value of a derivative instrument. See “Note 10 — Fair Value Measurements” for further discussion.

17

Contingent Consideration Arrangements

Percussion Earn-Out Obligation. As a result of the Percussion Acquisition, the Company assumed an earn-out obligation from Percussion Operating, where the Company could be required to pay up to $62.5 million in the aggregate if the average daily settlement price of WTI crude oil exceeds $60.00 per barrel for each of the 2023, 2024, and 2025 calendar years.

Contingent Eagle Ford Consideration. As a result of the Eagle Ford Divestiture, the Company received a contingent consideration arrangement from Ridgemar. The Company could receive up to $45.0 million if the average daily settlement price of WTI crude oil for 2024 is at least $80.00 per barrel. If the average daily settlement price of WTI crude oil for 2024 is less than $80.00 per barrel but at least $75.00 per barrel, then the Company would receive $20.0 million.

The Company determined that the Percussion Earn-Out Obligation and Contingent Eagle Ford Consideration receipt were not clearly and closely related to the Percussion Acquisition and Eagle Ford Divestiture membership interest purchase agreements, and therefore bifurcated these embedded features and recorded these derivatives at their acquisition date fair value and divestiture date fair value of $34.9 million and $10.9 million, respectively, in the consolidated financial statements. As of September 30, 2023, the estimated fair values of the Percussion Earn-Out Obligation and Contingent Eagle Ford Consideration were $46.4 million and $21.7 million, respectively, and are presented in “Fair value of derivatives” in the consolidated balance sheets.

Financial Statement Presentation and Settlements

The Company records its derivative instruments at fair value in the consolidated balance sheets and records changes in fair value, as well as settlements during the period, as “(Gain) loss on derivative contracts” in the consolidated statements of operations. The Company presents the fair value of derivative contracts on a net basis in the consolidated balance sheets as they are subject to master netting arrangements. The following presents the impact of this presentation to the Company’s recognized assets and liabilities for the periods indicated:

	As of September 30, 2023
	Presented without		As Presented with
	Effects of Netting	Effects of Netting	Effects of Netting
	(In thousands)
Derivative Assets
Commodity derivative instruments	$9,792	($8,596)	$1,196
Fair value of derivatives - current	$9,792	($8,596)	$1,196
Commodity derivative instruments	$4,270	($4,208)	$62
Contingent consideration arrangements	21,680	—	21,680
Fair value of derivatives - non-current	$25,950	($4,208)	$21,742
Derivative Liabilities
Commodity derivative instruments	($57,575)	$8,596	($48,979)
Contingent consideration arrangements	(12,210)	—	(12,210)
Fair value of derivatives - current	($69,785)	$8,596	($61,189)
Commodity derivative instruments	($14,805)	$4,208	($10,597)
Contingent consideration arrangements	(34,210)	—	(34,210)
Fair value of derivatives - non-current	($49,015)	$4,208	($44,807)

	As of December 31, 2022
	Presented without		As Presented with
	Effects of Netting	Effects of Netting	Effects of Netting
	(In thousands)
Derivative Assets
Fair value of derivatives - current	$51,984	($30,652)	$21,332
Fair value of derivatives - non-current	$1,343	($889)	$454
Derivative Liabilities
Fair value of derivatives - current	($46,849)	$30,652	($16,197)
Fair value of derivatives - non-current	($14,304)	$889	($13,415)

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The components of “(Gain) loss on derivative contracts” are as follows for the respective periods:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022	2023	2022
	(In thousands)
(Gain) loss on oil derivatives	$54,446	($157,731)	$18,165	$243,527
(Gain) loss on natural gas derivatives	(2,315)	22,881	2,380	56,800
Loss on NGL derivatives	2,933	—	2,933	4,771
Loss on contingent consideration arrangements	740	—	740	—
(Gain) loss on derivative contracts	$55,804	($134,850)	$24,218	$305,098

The components of “Cash received (paid) for commodity derivative settlements, net” and “Cash received (paid) for settlements of contingent consideration arrangements, net” are as follows for the respective periods:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022	2023	2022
	(In thousands)
Cash flows from operating activities
Cash received (paid) on oil derivatives	$1,680	($117,024)	($4,450)	($374,711)
Cash received (paid) on natural gas derivatives	(560)	(28,572)	17,816	(55,024)
Cash paid on NGL derivatives	(92)	—	(92)	(3,783)
Cash received (paid) for commodity derivative settlements, net	$1,028	($145,596)	$13,274	($433,518)
Cash received for settlements of contingent consideration arrangements, net (1)	$—	$—	$—	$6,492
Cash flows from investing activities
Cash paid for settlement of contingent consideration arrangement (1)	$—	$—	$—	($19,171)
Cash flows from financing activities
Cash received for settlement of contingent consideration arrangement (1)	$—	$—	$—	$8,512

(1)    See “Note 8 — Derivative Instruments and Hedging Activities” of the Notes to Consolidated Financial Statements in our 2022 Annual Report for discussion of the contingent consideration arrangements.

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Derivative Positions

Listed in the tables below are the outstanding oil, natural gas, and NGL derivative contracts as of September 30, 2023:

	For the Remainder	For the Full Year
Oil Contracts (WTI)	2023	2024
Swap Contracts
Total volume (Bbls)	—	1,076,300
Weighted average price per Bbl	$—	$81.66
Collar Contracts (Three-Way Collars)
Total volume (Bbls)	541,528	3,963,025
Weighted average price per Bbl
Ceiling (short call)	$70.95	$78.86
Floor (long put)	$55.00	$58.16
Floor (short put)	$45.00	$48.16
Collar Contracts (Two-Way Collars)
Total volume (Bbls)	993,455	—
Weighted average price per Bbl
Ceiling (short call)	$87.20	$—
Floor (long put)	$72.04	$—
CMA Roll Swap Contracts
Total volume (Bbls)	838,828	—
Weighted average price per Bbl	$0.30	$—

	For the Remainder	For the Full Year
Natural Gas Contracts (Henry Hub)	2023	2024
Swap Contracts
Total volume (MMBtu)	620,000	—
Weighted average price per MMBtu	$3.00	$—
Collar Contracts
Total volume (MMBtu)	2,201,104	8,598,557
Weighted average price per MMBtu
Ceiling (short call)	$5.37	$3.89
Floor (long put)	$3.14	$3.00
Natural Gas Contracts (Waha Basis Differential)
Swap Contracts
Total volume (MMBtu)	2,460,000	7,320,000
Weighted average price per MMBtu	($1.49)	($1.06)
Natural Gas Contracts (HSC Basis Differential)
Swap Contracts
Total volume (MMBtu)	2,760,000	14,640,000
Weighted average price per MMBtu	($0.29)	($0.42)

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	For the Remainder	For the Full Year
NGL Contracts (Mont Belvieu Natural Gasoline)	2023	2024
Swap Contracts
Total volume (Bbls)	43,105	—
Weighted average price per Bbl	$56.38	$—
NGL Contracts (Mont Belvieu Propane)
Swap Contracts
Total volume (Bbls)	35,754	—
Weighted average price per Bbl	$31.27	$—
NGL Contracts (Mont Belvieu Purity Ethane)
Swap Contracts
Total volume (Bbls)	35,095	—
Weighted average price per Bbl	$9.54	$—
NGL Contracts (Mont Belvieu Normal Butane)
Swap Contracts
Total volume (Bbls)	33,470	72,105
Weighted average price per Bbl	$35.56	$33.18
NGL Contracts (Mont Belvieu Isobutane)
Swap Contracts
Total volume (Bbls)	10,967	23,462
Weighted average price per Bbl	$35.42	$33.18

Note 10 — Fair Value Measurements

Accounting guidelines for measuring fair value establish a three-level valuation hierarchy for disclosure of fair value measurements. The valuation hierarchy categorizes assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. The three levels are defined as follows:

Level 1 – Observable inputs such as quoted prices in active markets at the measurement date for identical, unrestricted assets or liabilities.

Level 2 – Other inputs that are observable directly or indirectly, such as quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability.

Level 3 – Unobservable inputs for which there is little or no market data and for which the Company makes its own assumptions about how market participants would price the assets and liabilities.

Fair Value of Financial Instruments

Cash, Cash Equivalents, and Restricted Investments. The carrying amounts for these instruments approximate fair value due to the short-term nature or maturity of the instruments.

Debt. The carrying amount of borrowings outstanding under the Credit Facility approximates fair value as the borrowings bear interest at variable rates and are reflective of market rates. The following table presents the principal amounts of the Senior Notes with the fair values measured using quoted secondary market trading prices which are designated as Level 2 within the valuation hierarchy.

	September 30, 2023		December 31, 2022
	Principal Amount	Fair Value	Principal Amount	Fair Value
	(In thousands)
8.25% Senior Notes	$—	$—	$187,238	$186,719
6.375% Senior Notes	320,783	314,634	320,783	301,732
8.0% Senior Notes	650,000	650,800	650,000	616,935
7.5% Senior Notes	600,000	581,754	600,000	550,812
Total	$1,570,783	$1,547,188	$1,758,021	$1,656,198

Assets and Liabilities Measured at Fair Value on a Recurring Basis

Certain assets and liabilities are reported at fair value on a recurring basis in the consolidated balance sheets. The following methods and assumptions were used to estimate fair value:

Commodity Derivative Instruments. The fair value of commodity derivative instruments is derived using a third-party income approach valuation model that utilizes market-corroborated inputs that are observable over the term of the commodity derivative

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contract. The Company’s fair value calculations also incorporate an estimate of the counterparties’ default risk for commodity derivative assets and an estimate of the Company’s default risk for commodity derivative liabilities. As the inputs in the model are substantially observable over the term of the commodity derivative contract and as there is a wide availability of quoted market prices for similar commodity derivative contracts, the Company designates its commodity derivative instruments as Level 2 within the fair value hierarchy. See “Note 9 — Derivative Instruments and Hedging Activities” for further discussion.

Contingent Consideration Arrangements - Embedded Derivative Financial Instruments. The embedded options within the contingent consideration arrangements are considered financial instruments under ASC 815. The Company engages a third-party valuation specialist using an option pricing model approach to measure the fair value of the embedded options on a recurring basis. The valuation includes significant inputs such as forward oil price curves, time to expiration, and implied volatility. The model provides for the probability that the specified pricing thresholds would be met for each settlement period, estimates undiscounted payouts, and risk adjusts for the discount rates inclusive of adjustments for each of the counterparty’s credit quality. As these inputs are substantially observable for the full term of the contingent consideration arrangements, the inputs are considered Level 2 inputs within the fair value hierarchy. See “Note 9 - Derivative Instruments and Hedging Activities” for further discussion.

The following tables present the Company’s assets and liabilities measured at fair value on a recurring basis as of September 30, 2023 and December 31, 2022:

	September 30, 2023
	Level 1	Level 2	Level 3
	(In thousands)
Derivative Assets
Commodity derivative instruments	$—	$1,258	$—
Contingent consideration arrangements	—	21,680	—
Total net assets	$—	$22,938	$—
Derivative Liabilities
Commodity derivative instruments	$—	($59,576)	$—
Contingent consideration arrangements	—	(46,420)	—
Total net liabilities	$—	($105,996)	$—
	December 31, 2022
	Level 1	Level 2	Level 3
	(In thousands)
Commodity derivative assets	$—	$21,786	$—
Commodity derivative liabilities	$—	($29,612)	$—

There were no transfers between any of the fair value levels during any period presented.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

Acquisitions. The fair value of assets acquired and liabilities assumed are measured as of the acquisition date by a third-party valuation specialist using a combination of income and market approaches, which are not observable in the market and are therefore designated as Level 3 inputs. Significant inputs include expected discounted future cash flows from estimated reserve quantities, estimates for timing and costs to produce and develop reserves, oil and natural gas forward prices, and a risk adjusted discount rate. See “Note 5 –Acquisitions and Divestitures” for additional discussion.

Asset Retirement Obligations. The Company measures the fair value of asset retirement obligations as of the date a well begins drilling or when production equipment and facilities are installed using a discounted cash flow model based on inputs that are not observable in the market and that, therefore, are designated as Level 3 within the valuation hierarchy. Significant inputs to the fair value measurement of asset retirement obligations include estimates of the costs of plugging and abandoning oil and gas wells, removing production equipment and facilities, restoring the surface of the land as well as estimates of the economic lives of the oil and gas wells and future inflation rates.

Note 11 — Income Taxes

The Company provides for income taxes at the statutory rate of 21%. Reported income tax expense differs from the amount of income tax expense that would result from applying domestic federal statutory tax rates to pretax income. These differences primarily relate to non-deductible executive compensation expenses, restricted stock unit windfalls, changes in valuation allowances, and state income taxes.

For the three and nine months ended September 30, 2023, the Company recognized income tax expense of $0.5 million and income tax benefit of $206.4 million, respectively, as a result of the release of the valuation allowance recorded against the Company’s net deferred tax assets as discussed further below. For the three and nine months ended September 30, 2022, the Company recognized

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income tax expense of $3.4 million and $6.5 million, respectively, as a result of the full valuation allowance that was in place and the effect of state income taxes.

Deferred Tax Asset Valuation Allowance

Management monitors company-specific, oil and natural gas industry and worldwide economic factors and assesses the likelihood that the Company’s net deferred tax assets will be utilized prior to their expiration. As previously disclosed in the Company’s 2022 Annual Report, beginning in the second quarter of 2020 and through the fourth quarter of 2022, the Company maintained a valuation allowance against its net deferred tax assets. Considering all available evidence (both positive and negative), the Company concluded that it was more likely than not that the deferred tax assets would be realized and released the valuation allowance in the first quarter of 2023. This release resulted in deferred income tax benefit of $0.7 million and $206.1 million for the three and nine months ended September 30, 2023, respectively.

Note 12 — Share-Based Compensation

RSU Equity Awards

The following table summarizes activity for restricted stock units that may be settled in common stock (“RSU Equity Awards”) for the nine months ended September 30, 2023:

	Nine Months Ended September 30, 2023
	RSU Equity Awards (In thousands)	Weighted Average Grant Date Fair Value
Unvested, beginning of the period	800	$44.79
Granted	539	$34.54
Vested	(369)	$39.89
Forfeited	(128)	$44.00
Unvested, end of the period	842	$40.49

Grant activity for the nine months ended September 30, 2023 primarily consisted of RSU Equity Awards granted to executives and employees as part of the annual grant of long-term equity incentive awards with a weighted-average grant date fair value of $34.54.

The aggregate fair value of RSU Equity Awards that vested during the nine months ended September 30, 2023 was $12.3 million. As of September 30, 2023, unrecognized compensation costs related to unvested RSU Equity Awards were $25.3 million and will be recognized over a weighted average period of 2.0 years.

Cash-Settled Awards

As of September 30, 2023 and December 31, 2022, the Company had a total liability of $3.4 million and $6.5 million, respectively, for outstanding Cash-Settled Awards (as defined below). As of December 31, 2022, Cash-Settled Awards consisted of restricted stock unit awards that may be settled in cash (“Cash-Settled RSU Awards”) and stock appreciation rights to be settled in cash (“Cash SARs” and, collectively with the Cash-Settled RSU Awards, the “Cash-Settled Awards”). As of September 30, 2023, there were no Cash-Settled RSU Awards outstanding.

Share-Based Compensation Expense (Benefit), Net

Share-based compensation expense associated with the RSU Equity Awards and the Cash-Settled Awards is included in “General and administrative” in the consolidated statements of operations. The following table presents share-based compensation expense (benefit), net for the periods indicated:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022*	2023	2022*
	(In thousands)
RSU Equity Awards	$3,906	$3,892	$11,613	$11,581
Cash-Settled Awards	49	(2,151)	(2,089)	(7,154)
Total share-based compensation expense (benefit), net	$3,955	$1,741	$9,524	$4,427

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

See “Note 10 — Share-Based Compensation” of the Notes to Consolidated Financial Statements in the 2022 Annual Report for details of the Company’s equity-based incentive plans. 

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Note 13 - Stockholders’ Equity

On May 2, 2023, the board of directors (the “Board”) of the Company approved a share repurchase program (the “Share Repurchase Program”), pursuant to which the Company is authorized to repurchase up to $300.0 million of its outstanding common stock through the second quarter of 2025. Repurchases under the Share Repurchase Program may be made, from time to time, in amounts and at prices the Company deems appropriate and will be subject to a variety of factors, including the market price of the Company’s common stock, general market and economic conditions and applicable legal requirements. The Share Repurchase Program may be suspended, modified or discontinued by the Board at any time without prior notice.

During the three months ended September 30, 2023, the Company repurchased and retired 386,719 shares of common stock at a weighted average purchase price of $38.72 per common share for a total cost of approximately $15.0 million. As of September 30, 2023, the remaining authorized repurchase amount under the Share Repurchase Program was $285.0 million.

Note 14 — Accounts Receivable, Net

	September 30, 2023	December 31, 2022
	(In thousands)
Oil and natural gas receivables	$169,254	$174,107
Joint interest receivables	35,777	16,778
Other receivables	58,531	48,277
Total	263,562	239,162
Allowance for credit losses	(1,168)	(2,034)
Total accounts receivable, net	$262,394	$237,128

Note 15 — Accounts Payable and Accrued Liabilities

	September 30, 2023	December 31, 2022
	(In thousands)
Accounts payable	$254,568	$191,133
Revenues and royalties payable	230,918	244,408
Accrued capital expenditures	71,678	58,395
Accrued interest	28,365	42,297
Total accounts payable and accrued liabilities	$585,529	$536,233

Note 16 — Supplemental Cash Flow

	Nine Months Ended September 30,
	2023	2022*
	(In thousands)
Supplemental cash flow information:
Interest paid	$142,616	$159,832
Income taxes paid (1)	4,477	—
Non-cash investing and financing activities:
Change in accrued capital expenditures	$41,505	$13,966
Change in asset retirement costs	5,956	3,665

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

(1)    The Company did not pay or receive a refund for any federal income tax for the nine months ended September 30, 2022. For the nine months ended September 30, 2023 and 2022, the Company had net payments of $2.3 million and $0.2 million, respectively, for state income taxes.

Note 17 — Subsequent Events

Credit Agreement Reaffirmation

See “Note 8 — Borrowings” for discussion of the results of the Company’s fall 2023 borrowing base redetermination.

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Special Note Regarding Forward-Looking Statements

This Form 10-Q includes “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 statements involve known and unknown risks, uncertainties and other factors that may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by the forward-looking statements. In some cases, you can identify forward-looking statements in this Form 10-Q by words such as “anticipate,” “project,” “intend,” “estimate,” “expect,” “believe,” “predict,” “budget,” “projection,” “goal,” “plan,” “forecast,” “target” or similar expressions.

All statements, other than statements of historical facts, included in this Form 10-Q that address activities, events or developments that we expect or anticipate will or may occur in the future are forward-looking statements. Without limiting the generality of the foregoing, forward-looking statements may include statements regarding the following (to the extent not historical):

•our oil and natural gas reserve quantities and the discounted present value of these reserves;

•the amount and nature of our capital expenditures;

•our future drilling and development plans and our potential drilling locations;

•the timing and amount of future capital and operating costs;

•production decline rates from our wells being greater than expected;

•commodity price risk management activities and the impact on our average realized prices;

•business strategies and plans of management;

•our ability to efficiently integrate recent acquisitions; and

•prospect development and property acquisitions.

We caution you that the forward-looking statements contained in this Form 10-Q are subject to all of the risks and uncertainties, many of which are beyond our control, incident to the exploration for and development, production and sale of oil and natural gas. We disclose these and other important factors that could cause our actual results to differ materially from our expectations under “Risk Factors” in Part I, Item 1A of our 2022 Annual Report. These factors include:

•the volatility of oil, natural gas and NGL prices or a prolonged period of low oil, natural gas or NGL prices;

•general economic conditions, including the availability of credit, access to existing lines of credit, inflation and rising interest rates;

•changes in the supply of and demand for oil and natural gas, including as a result of actions by, or disputes among, members of OPEC and other oil and natural gas producing countries, such as Russia, with respect to production levels or other matters related to the price of oil;

•the uncertainty of estimates of oil and natural gas reserves;

•impairments;

•the impact of competition;

•the availability and cost of drilling rigs, pressure pumping equipment and crews, other equipment, supplies, water, personnel and oil field services;

•our dependency on third-party service providers;

•restrictions on our ability to obtain, recycle and dispose of water;

•operating hazards inherent in the exploration for and production of oil and natural gas;

•difficulties encountered during the exploration for and production of oil and natural gas;

•physical risks arising from climate change;

•the potential impact of future drilling on production from existing wells;

•difficulties encountered in delivering oil and natural gas to commercial markets and the availability and capacity of gas processing facilities and pipelines and other transportation operations owned and operated by third parties;

•the uncertainty of our ability to attract capital and obtain financing on favorable terms;

•our ability to keep pace with technological developments in our industry;

•compliance with, or the effect of changes in, the extensive governmental regulations regarding the oil and natural gas business including those related to climate change and greenhouse gases;

•the impact of government regulation, including regulation of hydraulic fracturing and water disposal wells;

•climate-related transition risks, including evolving climate change legislation, fuel conservation measures, technological advances and negative shift in market perception towards the oil and natural gas industry, which could result in increased operating expenses and capital costs, financial risks and potential reduction in demand for oil and natural gas;

•any increase in severance or similar taxes;

•the financial impact of accounting regulations and critical accounting policies;

•the comparative cost of alternative fuels;

•credit risk relating to the risk of loss as a result of non-performance by our counterparties;

•cyberattacks on the Company or on systems and infrastructure used by the oil and natural gas industry;

•weather conditions; and

•risks associated with acquisitions, including the Percussion Acquisition.

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Should one or more of these risks or uncertainties occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. Additional risks or uncertainties that are not currently known to us, that we currently deem to be immaterial, or that could apply to any company could also materially adversely affect our business, financial condition, or future results. Any forward-looking statement speaks only as of the date of which such statement is made and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law.

In addition, we caution that reserve engineering is a process of estimating oil and natural gas accumulated underground and cannot be measured exactly. Accuracy of reserve estimates depends on a number of factors including data available at the point in time, engineering interpretation of the data, and assumptions used by the reserve engineers as it relates to price and cost estimates and recoverability. New results of drilling, testing, and production history may result in revisions of previous estimates and, if significant, would impact future development plans. As such, reserve estimates may differ from actual results of oil and natural gas quantities ultimately recovered.

Except as required by applicable law, all forward-looking statements attributable to us are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue.

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

The following management’s discussion and analysis describes the principal factors affecting our results of operations, liquidity, capital resources and contractual cash obligations. This discussion should be read in conjunction with our consolidated financial statements and accompanying notes included under Part I, Item I, “Financial Statements” of this Form 10-Q, as well as our consolidated financial statements, accompanying notes and Management’s Discussion and Analysis of Financial Condition and Results of Operations included in our 2022 Annual Report.

Financial information for all prior periods has been recast to reflect the retrospective application of the successful efforts method of accounting, as discussed under “Note 2 — Summary of Significant Accounting Policies” of the Notes to Consolidated Financial Statements in this Form 10-Q.

General

We are an independent oil and natural gas company focused on the acquisition, exploration and sustainable development of high-quality assets in the Permian Basin in West Texas. Our operating culture is centered on responsible development of hydrocarbon resources, safety and the environment, which we believe strengthens our operational performance. Our drilling activity is predominantly focused on the horizontal development of several prospective intervals in the Permian, including multiple layers of the Wolfcamp and Bone Springs formations and the Spraberry shale. We have assembled a decade-plus inventory of potential horizontal well locations and intend to add to this inventory through delineation drilling of emerging zones on our existing acreage and through the acquisition of additional locations through working interest acquisitions, leasing programs, acreage purchases, joint ventures and asset swaps.

Recent Developments and Overview

Share Repurchase Program

During the three months ended September 30, 2023, we repurchased and retired 386,719 shares of common stock at a weighted average purchase price of $38.72 per common share for a total cost of $15.0 million. See “Note 13 — Stockholders’ Equity” for additional details.

Acquisition and Divestiture

On July 3, 2023, we closed the Percussion Acquisition for total consideration of approximately $458.5 million and the Eagle Ford Divestiture for cash consideration of approximately $549.3 million, both subject to customary post-closing purchase price adjustments. See “Note 5 — Acquisitions and Divestitures” for additional details.

Redemption of 8.25% Senior Notes due 2025

On July 3, 2023, we delivered a redemption notice with respect to all $187.2 million of our outstanding 8.25% Senior Notes, which were redeemed on August 2, 2023 using borrowings under our Credit Facility.

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Third Quarter 2023 Highlights

•Operated drilling and turned in-line activity for the three months ended September 30, 2023 along with our drilled but uncompleted and producing wells as of September 30, 2023 are summarized in the table below.

    

	Three Months Ended September 30, 2023				As of September 30, 2023
	Drilled		Turned In-Line		Drilled But Uncompleted		Producing
Region	Gross	Net	Gross	Net	Gross	Net	Gross	Net
Permian	24	19.6	33	30.0	25	21.1	917	809.5

    

•Operational capital expenditures, exclusive of leasehold, for the third quarter of 2023 were $251.0 million.

•Recorded net income for the three months ended September 30, 2023 of $119.5 million, or $1.75 per diluted share, compared to net income for the three months ended September 30, 2022 of $502.0 million, or $8.11 per diluted share. The variance between the periods was primarily due to a decrease in operating revenues in the third quarter of 2023 as a result of an approximate 26% decrease in the total average realized sales price and an approximate 5% decrease in production, as well as a loss on derivative contracts of $55.8 million during the third quarter of 2023 compared to a gain of approximately $134.9 million during the third quarter of 2022.

Results of Operations

This section discusses the material changes in the Company’s results of operations for the three months ended September 30, 2023 as compared to the three months ended June 30, 2023 and for the nine months ended September 30, 2023 as compared to the nine months ended September 30, 2022. Detailed financial information with respect to the Company’s results of operations for the three months ended June 30, 2023 can be found in Part I, Item 1, “Financial Statements” of the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2023.

Production

	Three Months Ended							Nine Months Ended September 30,
	September 30, 2023		June 30, 2023		Change	% Change		2023		2022		Change	% Change
Total production
Oil (MBbls)
Permian	5,310		4,671		639	14	%	14,256		13,326		930	7	%
Eagle Ford	28		1,066		(1,038)	(97	%)	2,233		4,221		(1,988)	(47	%)
Total oil	5,338		5,737		(399)	(7	%)	16,489		17,547		(1,058)	(6	%)
Natural gas (MMcf)
Permian	11,644		10,409		1,235	12	%	31,341		26,506		4,835	18	%
Eagle Ford	44		1,292		(1,248)	(97	%)	2,672		4,578		(1,906)	(42	%)
Total natural gas	11,688		11,701		(13)	—	%	34,013		31,084		2,929	9	%
NGLs (MBbls)
Permian	2,069		1,816		253	14	%	5,457		4,779		678	14	%
Eagle Ford	6		229		(223)	(97	%)	457		767		(310)	(40	%)
Total NGLs	2,075		2,045		30	1	%	5,914		5,546		368	7	%
Total production (MBoe)
Permian	9,320		8,222		1,098	13	%	24,937		22,523		2,414	11	%
Eagle Ford	41		1,510		(1,469)	(97	%)	3,135		5,751		(2,616)	(45	%)
Total barrels of oil equivalent	9,361		9,732		(371)	(4	%)	28,072		28,274		(202)	(1	%)
Total daily production (Boe/d)	101,741		106,948		(5,207)	(5	%)	102,826		103,569		(743)	(1	%)
Percent of total daily production
Oil	57	%	59	%		(3	%)	59	%	62	%		(5	%)
Natural gas	21	%	20	%		5	%	20	%	18	%		11	%
NGLs	22	%	21	%		5	%	21	%	20	%		5	%

The decreases in production for both the three months ended September 30, 2023 and the nine months ended September 30, 2023 compared to the three months ended June 30, 2023 and the nine months ended September 30, 2022, respectively, were primarily due to the Eagle Ford Divestiture, as well as oil volumes that were negatively impacted by weather-related power and midstream disruptions in the third quarter and a lower-than-expected oil mix from recent completions in the western portion of our Permian acreage, partially offset by the Percussion Acquisition.

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Pricing

	Three Months Ended					Nine Months Ended September 30,
	September 30, 2023	June 30, 2023	Change	% Change		2023	2022	Change	% Change
Benchmark prices (1)
WTI (per Bbl)	$82.18	$73.75	$8.43	11	%	$77.37	$98.14	($20.77)	(21	%)
Henry Hub (per Mcf)	2.66	2.32	0.34	15	%	2.58	6.67	(4.09)	(61	%)
Average realized sales price (excluding impact of derivative settlements)
Oil (per Bbl)
Permian	$82.19	$73.45	$8.74	12	%	$77.34	$99.62	($22.28)	(22	%)
Eagle Ford	79.61	73.80	5.81	8	%	75.01	99.84	(24.83)	(25	%)
Total oil	82.18	73.52	8.66	12	%	77.02	99.67	(22.65)	(23	%)
Natural gas (per Mcf)
Permian	2.13	1.15	0.98	85	%	1.79	5.98	(4.19)	(70	%)
Eagle Ford	4.82	1.93	2.89	150	%	2.64	6.84	(4.20)	(61	%)
Total natural gas	2.14	1.23	0.91	74	%	1.85	6.11	(4.26)	(70	%)
NGL (per Bbl)
Permian	22.25	20.14	2.11	10	%	22.22	38.34	(16.12)	(42	%)
Eagle Ford	74.33	17.72	56.61	319	%	20.26	35.82	(15.56)	(43	%)
Total NGLs	22.40	19.87	2.53	13	%	22.06	37.99	(15.93)	(42	%)
Total average realized sales price (per Boe)
Permian	54.43	47.63	6.80	14	%	51.32	74.12	(22.80)	(31	%)
Eagle Ford	70.41	56.44	13.97	25	%	58.63	83.50	(24.87)	(30	%)
Total average realized sales price	$54.50	$49.00	$5.50	11	%	$52.14	$76.02	($23.88)	(31	%)

(1)    Reflects calendar average daily spot market prices.

Revenues

	Oil		Natural Gas		NGLs		Total
	(In thousands)
Revenues for the three months ended June 30, 2023 (1)	$421,775		$14,423		$40,629		$476,827
Volume increase (decrease)	(29,407)		(16)		596		(28,827)
Price increase	46,297		10,638		5,264		62,199
Net increase	16,890		10,622		5,860		33,372
Revenues for the three months ended September 30, 2023 (1)	$438,665		$25,045		$46,489		$510,199
Percent of total revenues	86	%	5	%	9	%

(1)    Excludes sales of oil and gas purchased from third parties and sold to our customers.

The increase in revenues for the three months ended September 30, 2023 compared to the three months ended June 30, 2023 was primarily due to an 11% increase in the average realized sales price, which increased to $54.50 per Boe from $49.00 per Boe, as shown above, partially offset by a 5% decrease in production as described above.

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	Oil		Natural Gas		NGLs		Total
	(In thousands)
Revenues for the nine months ended September 30, 2022(1)	$1,748,913		$189,907		$210,696		$2,149,516
Volume increase (decrease)	(105,451)		17,895		13,981		(73,575)
Price decrease	(373,466)		(144,748)		(94,189)		(612,403)
Net decrease	(478,917)		(126,853)		(80,208)		(685,978)
Revenues for the nine months ended September 30, 2023 (1)	$1,269,996		$63,054		$130,488		$1,463,538
Percent of total revenues	87	%	4	%	9	%

(1)    Excludes sales of oil and gas purchased from third parties and sold to our customers.

The decrease in revenues for the nine months ended September 30, 2023 compared to the same period of 2022 was primarily due to a 31% decrease in the average realized sales price, which decreased to $52.14 per Boe from $76.02 per Boe, as well as a 1% decrease in production, as shown above.

Operating Expenses

Lease Operating Expenses

	Three Months Ended
	September 30, 2023	Per	June 30, 2023	Per	Total Change			Boe Change
		Boe		Boe	$	%		$	%
	(In thousands, except per Boe and % amounts)
Permian	$73,685	$7.91	$61,021	$7.42	$12,664	21	%	$0.49	7	%
Eagle Ford	(160)	(3.90)	15,767	10.44	(15,927)	(101	%)	(14.34)	(137	%)
Lease operating	$73,525	$7.85	$76,788	$7.89	($3,263)	(4	%)	($0.04)	(1	%)
	Nine Months Ended September 30,
		Per		Per	Total Change			Boe Change
	2023	Boe	2022	Boe	$	%		$	%
	(In thousands, except per Boe and % amounts)
Permian	$192,921	$7.74	$163,273	$7.25	$29,648	18	%	$0.49	7	%
Eagle Ford	32,494	10.36	53,116	9.24	(20,622)	(39	%)	1.12	12	%
Lease operating	$225,415	$8.03	$216,389	$7.65	$9,026	4	%	$0.38	5	%

The decrease in lease operating expenses for the three months ended September 30, 2023 compared to the three months ended June 30, 2023 was primarily due to lower operating expenses associated with properties acquired in the Percussion Acquisition as compared to the properties disposed of in the Eagle Ford Divestiture as well as lower chemical costs and workover expense, partially offset by increases in other certain operating costs such as saltwater disposal and fuel and power. The decrease in lease operating expenses per Boe for the three months ended September 30, 2023 compared to the three months ended June 30, 2023 was primarily driven by the reduction in operating costs described above.

The increase in lease operating expenses, as well as the increase in lease operating expenses per Boe, for the nine months ended September 30, 2023 compared to the same period of 2022 was primarily due to increases in certain operating expenses such as saltwater disposal and fuel and power.

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Production and Ad Valorem Taxes

	Three Months Ended
	September 30, 2023		Per	June 30, 2023		Per	Total Change			Boe Change
			Boe			Boe	$	%		$	%
	(In thousands, except per Boe and % amounts)
Permian	$30,407		$3.26	$19,739		$2.40	$10,668	54	%	$0.86	36	%
Eagle Ford	185		4.51	4,967		3.29	(4,782)	(96	%)	1.22	37	%
Production and ad valorem taxes	$30,592		$3.27	$24,706		$2.54	$5,886	24	%	$0.73	29	%
Percent of total revenues	6.0	%		5.2	%			0.8	%
	Nine Months Ended September 30,
			Per			Per	Total Change			Boe Change
	2023		Boe	2022		Boe	$	%		$	%
	(In thousands, except per Boe and % amounts)
Permian	$75,543		$3.03	$96,289		$4.29	($20,746)	(22	%)	($1.26)	(29	%)
Eagle Ford	12,476		3.98	29,552		5.14	(17,076)	(58	%)	(1.16)	(23	%)
Production and ad valorem taxes	$88,019		$3.14	$125,841		$4.45	($37,822)	(30	%)	($1.31)	(29	%)
Percent of total revenues	6.0	%		5.9	%			0.1	%

The increase in production and ad valorem taxes for the three months ended September 30, 2023 compared to the three months ended June 30, 2023 was primarily related to a 7% increase in total revenues which increased production taxes.

The decrease in production and ad valorem taxes for the nine months ended September 30, 2023 compared to the same period of 2022 was primarily related to a 32% decrease in total revenues which decreased production taxes, partially offset by an increase in ad valorem taxes due to higher expected property tax valuations as a result of higher commodity prices during 2022 compared to 2021. The increase in production and ad valorem taxes as a percentage of total revenues for the nine months ended September 30, 2023 compared to the same period of 2022 was primarily due to an increase in ad valorem taxes during the nine months ended September 30, 2023, as discussed above, with a decrease in total revenues during the nine months ended September 30, 2023.

Gathering, Transportation and Processing Expenses

	Three Months Ended
	September 30, 2023	Per	June 30, 2023	Per	Total Change			Boe Change
		Boe		Boe	$	%		$	%
	(In thousands, except per Boe and % amounts)
Permian	$27,209	$2.92	$24,407	$2.97	$2,802	11	%	($0.05)	(2	%)
Eagle Ford	46	1.12	2,931	1.94	(2,885)	(98	%)	(0.82)	(42	%)
Gathering, transportation and processing	$27,255	$2.91	$27,338	$2.81	($83)	—	%	$0.10	4	%
	Nine Months Ended September 30,
		Per		Per	Total Change			Boe Change
	2023	Boe	2022	Boe	$	%		$	%
	(In thousands, except per Boe and % amounts)
Permian	$74,323	$2.98	$60,805	$2.70	$13,518	22	%	$0.28	10	%
Eagle Ford	6,247	1.99	10,812	1.88	(4,565)	(42	%)	0.11	6	%
Gathering, transportation and processing	$80,570	$2.87	$71,617	$2.53	$8,953	13	%	$0.34	13	%

The decrease in gathering, transportation and processing expenses for the three months ended September 30, 2023 compared to the three months ended June 30, 2023 was primarily related to the 5% decrease in production volumes between the two periods. The increase in gathering, transportation and processing expenses per Boe between the third quarter of 2023 and the second quarter of 2023 was immaterial.

The increase in gathering, transportation and processing expenses, as well as the increase in gathering, transportation and processing expenses per Boe, for the nine months ended September 30, 2023 compared to the same period of 2022 was primarily related to a new gathering agreement put into place during the nine months ended September 30, 2023.

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Exploration Expenses

	Three Months Ended
	September 30, 2023	Per	June 30, 2023	Per	Total Change			Boe Change
		Boe		Boe	$	%		$	%
	(In thousands, except per Boe and % amounts)
Exploration	$3,588	$0.38	$1,882	$0.19	$1,706	91	%	$0.19	100	%
	Nine Months Ended September 30,
		Per		Per	Total Change			Boe Change
	2023	Boe	2022	Boe	$	%		$	%
	(In thousands, except per Boe and % amounts)
Exploration	$7,702	$0.27	$7,237	$0.26	$465	6	%	$0.01	4	%

The increase in exploration expense for the three months ended September 30, 2023 compared to the three months ended June 30, 2023 was primarily attributable to the purchase of additional seismic data associated with acreage acquired in the Percussion Acquisition.

For the nine months ended September 30, 2023 compared to the same period in 2022, exploration expense increased by an immaterial amount.

Depreciation, Depletion and Amortization (“DD&A”). The following table sets forth the components of our DD&A for the periods indicated:

	Three Months Ended				Nine Months Ended September 30,
	September 30, 2023		June 30, 2023		2023		2022
	Amount	Per Boe	Amount	Per Boe	Amount	Per Boe	Amount	Per Boe
	(In thousands, except per Boe)
DD&A of proved oil and gas properties	$136,980	$14.64	$125,394	$12.88	$385,863	$13.75	$352,998	$12.48
Depreciation of other property and equipment	338	0.04	352	0.04	1,080	0.03	1,313	0.05
Amortization of other assets	487	0.05	650	0.07	1,927	0.07	2,200	0.08
Accretion of asset retirement obligations	793	0.08	952	0.10	3,041	0.11	2,983	0.10
DD&A	$138,598	$14.81	$127,348	$13.09	$391,911	$13.96	$359,494	$12.71

The increase in DD&A and DD&A per Boe for the three months ended September 30, 2023 compared to the three months ended June 30, 2023 was primarily attributable to the cessation of depletion on the assets disposed of with the Eagle Ford Divestiture as a result of being classified as assets held for sale during the second quarter of 2023 and the inclusion of the assets acquired in the Percussion Acquisition for all of the third quarter of 2023.

The increase in DD&A and DD&A per Boe for the nine months ended September 30, 2023 compared to the same period in 2022 was primarily attributable to higher proved oil and gas property balances as a result of the capital expenditures throughout 2022 and the nine months ended September 30, 2023, partially offset by the cessation of depletion on the assets associated with the Eagle Ford Divestiture as a result of being classified as assets held for sale during the second quarter of 2023.

See “Note 5 — Acquisitions and Divestitures” for additional details regarding the Eagle Ford Divestiture.

General and Administrative (“G&A”)

	Three Months Ended
	September 30, 2023	Per	June 30, 2023	Per	Total Change			Boe Change
		Boe		Boe	$	%		$	%
	(In thousands, except per Boe and % amounts)
General and administrative	$29,339	$3.13	$29,768	$3.06	($429)	(1	%)	$0.07	2	%
	Nine Months Ended September 30,
		Per		Per	Total Change			Boe Change
	2023	Boe	2022	Boe	$	%		$	%
	(In thousands, except per Boe and % amounts)
General and administrative	$86,905	$3.10	$71,485	$2.53	$15,420	22	%	$0.57	23	%

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For the three months ended September 30, 2023 compared to the three months ended June 30, 2023, G&A decreased by an immaterial amount.

The increase in G&A for the nine months ended September 30, 2023 compared to the same period in 2022 was primarily due to an increase in employee-related costs as well as an increase in stock compensation expense between the two periods.

Impairment of Oil and Gas Properties. We recognized an impairment of oil and gas properties in the second quarter of 2023 of $406.9 million as the fair value less cost to sell was less than the carrying amount of the net assets associated with the Eagle Ford Divestiture that were classified as assets held for sale. We did not recognize an impairment of oil and gas properties for the three months ended September 30, 2023 or the nine months ended September 30, 2022.

Other Income and Expenses

Interest Expense. The following table sets forth the components of our interest expense for the periods indicated:

	Three Months Ended			Nine Months Ended September 30,
	September 30, 2023	June 30, 2023	Change	2023	2022	Change
	(In thousands)
Interest expense on Senior Notes	$30,765	$33,224	($2,459)	$97,213	$91,470	$5,743
Interest expense on second lien notes	—	—	—	—	13,825	(13,825)
Interest expense on Credit Facility	9,627	11,397	(1,770)	31,471	25,989	5,482
Amortization of debt issuance costs, premiums and discounts	2,733	2,615	118	7,979	9,680	(1,701)
Other interest expense	24	3	21	31	56	(25)
Interest expense	$43,149	$47,239	($4,090)	$136,694	$141,020	($4,326)

Interest expense for the three months ended September 30, 2023 was $43.1 million, a decrease as compared to the three months ended June 30, 2023 as a result of the redemption of our 8.25% Senior Notes during the third quarter of 2023 as well as decreased borrowings under the Credit Facility.

Interest expense for the nine months ended September 30, 2023 was $136.7 million, a decrease as compared to the nine months ended September 30, 2022 as a result of the redemption of our 9.0% second lien notes in June 2022 and our 8.25% Senior Notes, partially offset by an increase in interest expense due to the issuance of our 7.5% Senior Notes due 2030 in June 2022 as well as increases in interest rates on our outstanding borrowings under the Credit Facility.

(Gain) Loss on Derivative Contracts. The net (gain) loss on derivative contracts for the periods indicated includes the following:

	Three Months Ended		Nine Months Ended September 30,
	September 30, 2023	June 30, 2023	2023	2022
	(In thousands)
(Gain) loss on oil derivatives	$54,446	($12,937)	$18,165	$243,527
(Gain) loss on natural gas derivatives	(2,315)	6,996	2,380	56,800
Loss on NGL derivatives	2,933	—	2,933	4,771
Gain on contingent consideration arrangements	740	—	740	—
(Gain) loss on derivative contracts	$55,804	($5,941)	$24,218	$305,098

See “Note 9 — Derivative Instruments and Hedging Activities” and “Note 10 — Fair Value Measurements” for additional information.

Income Tax Expense. We recorded income tax expense of $0.5 million and income tax benefit of $206.4 million for the three and nine months ended September 30, 2023, respectively, compared to income tax expense of $3.4 million and $6.5 million for the three and nine months ended September 30, 2022, respectively. The changes from the statutory income tax rate for the three and nine months ended September 30, 2023 is a result of releasing the valuation allowance that was in place against our net deferred tax assets. See “Note 11 — Income Taxes” for further discussion.

Liquidity and Capital Resources

Pricing Outlook. Oil prices continue to remain volatile as the daily NYMEX benchmark price for oil ranged between approximately $70 and $94 per barrel during the third quarter of 2023. While we saw a wide range during the second quarter of 2023 and the average price for the third quarter of 2023 increased approximately 17% as compared to the second quarter of 2023, the average price for the third quarter of 2023 remained significantly below the average for 2022. Additionally, during the third quarter of 2023, the daily

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NYMEX benchmark price for natural gas was $2.66 per mcf, a 15% increase as compared to the second quarter of 2023, but over a 59% decrease from the average for 2022. We expect to continue to see volatility in oil prices, as well as natural gas and NGL prices.

Capital Efficiency Outlook. We recently transitioned to a business unit design in our operations group to improve focus on capital efficiency and capital allocation. We have identified structural drilling efficiency gains from well design changes and expect to continue to identify incremental structural efficiency gains as we move into 2024. The identified improvements are expected to reduce our 2024 average total well costs, including facilities, by over 15%.

2023 Capital Budget and Funding Strategy. Our primary uses of capital are for the exploration and development of our oil and natural gas properties, where our 2023 planned capital expenditures are $960.0 million to $980.0 million. Because we are the operator of a high percentage of our properties, we can control the well design and the development pace associated with our capital expenditures. We plan our capital expenditure program to achieve disciplined reinvestment rates to drive capital efficiency through an enhanced multi-zone, scaled development program.

We believe that existing cash and cash equivalents, cash flows from operations and available borrowings under our Credit Facility will be sufficient to support working capital, capital expenditures and other cash requirements for at least the next 12 months and, based on our current expectations, for the foreseeable future thereafter. Our future capital requirements, both near-term and long-term, will depend on many factors, including, but not limited to, commodity prices, market conditions, our available liquidity and financing, acquisitions and divestitures of oil and gas properties, the availability of drilling rigs and completion crews, the cost of completion services, success of drilling programs, land and industry partner issues, weather delays, the acquisition of leases with drilling commitments, and other factors.

Historically, our primary sources of capital have been cash flows from operations, borrowings under our credit facility, proceeds from the issuance of debt securities and public equity offerings, and asset dispositions. We regularly consider which resources, including cash flows from operations and debt and equity financings, are available to meet our future financial obligations, planned capital expenditures and liquidity requirements. In addition, we may consider divesting certain properties or assets that are not part of our core business or are no longer deemed essential to our future growth or enter into joint venture agreements, provided we are able to divest such assets or enter into joint venture agreements on terms that are acceptable to us.

Depending upon our actual and anticipated sources and uses of liquidity, prevailing market conditions and other factors, we may, from time to time, seek to retire or repurchase our outstanding debt or equity securities through cash purchases in the open market or through privately negotiated transactions or otherwise. The amounts involved in any such transactions, individually or in aggregate, may be material. See “Note 13 — Stockholders’ Equity” for information regarding our Share Repurchase Program.

Overview of Cash Flow Activities. Cash and cash equivalents was $3.5 million and $3.4 million as of September 30, 2023 and December 31, 2022, respectively.

	Nine Months Ended September 30,
	2023	2022
	(In thousands)
Net cash provided by operating activities	$794,263	$1,021,686
Net cash used in investing activities	(480,842)	(661,516)
Net cash provided by (used in) financing activities	(313,360)	(365,702)
Net change in cash and cash equivalents	$61	($5,532)

Operating Activities. For the nine months ended September 30, 2023, net cash provided by operating activities was $794.3 million compared to $1,021.7 million for the same period in 2022. The change in net cash provided by operating activities was predominantly attributable to the following:

•A decrease in revenue primarily driven by a 31% decrease in total average realized sales price, and a 1% decrease in production volumes, largely offset by

•A decrease in the cash paid for commodity derivative settlements.

Production, realized prices, and operating expenses are discussed in Results of Operations. See “Note 9 — Derivative Instruments and Hedging Activities” and “Note 10 — Fair Value Measurements” for a reconciliation of the components of our derivative contracts and disclosures related to derivative instruments including their composition and valuation. 

Investing Activities. For the nine months ended September 30, 2023, net cash used in investing activities was $480.8 million compared to $661.5 million for the same period in 2022. The change in net cash used in investing activities was primarily attributable to cash paid for the Percussion Acquisition and an increase in operational capital expenditures, partially offset by proceeds from the Eagle Ford Divestiture and a decrease in cash paid for the settlement of contingent consideration agreements.

Financing Activities. We finance a portion of our capital expenditures, acquisitions and working capital requirements with borrowings under our Credit Facility, term debt and equity offerings. For the nine months ended September 30, 2023, net cash used in financing

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activities was $313.4 million compared to net cash used in financing activities of $365.7 million for the same period of 2022. The change was primarily attributable to the redemption of the 8.25% Senior Notes and the initiation of our Share Repurchase Program during the nine months ended September 30, 2023 compared to the redemptions of the 6.125% Senior Notes and Second Lien Notes, partially offset by the issuance of the 7.50% Senior Notes during the nine months ended September 30, 2022.

Credit Facility. As of September 30, 2023, our Credit Facility had a maximum credit amount of $5.0 billion, a borrowing base of $2.0 billion and an elected commitment amount of $1.5 billion, with borrowings outstanding of $396.0 million at a weighted average interest rate of 7.50%, and $21.4 million in letters of credit outstanding. See “Note 8 — Borrowings” for additional information related to the Credit Facility.

Redemption of 8.25% Senior Notes. On August 2, 2023, we redeemed all $187.2 million of our outstanding 8.25% Senior Notes using borrowings under our Credit Facility. See “Note 8 – Borrowings” of the Notes to our Consolidated Financial Statements for additional information on our long-term debt.

Material Cash Requirements. As of September 30, 2023, we have financial obligations associated with our outstanding long-term debt, including interest payments and principal repayments. See “Note 7 — Borrowings” of the Notes to Consolidated Financial Statements in our 2022 Annual Report for further discussion of the contractual commitments under our debt agreements, including the timing of principal repayments. Additionally, we have operational obligations associated with long-term, non-cancelable leases, drilling rig contracts, frac service contracts, gathering, processing and transportation service agreements and estimates of future asset retirement obligations. See “Note 14 — Asset Retirement Obligations” and “Note 17 — Commitments and Contingencies” of the Notes to Consolidated Financial Statements in our 2022 Annual Report for additional details.

On July 3, 2023, we completed the Percussion Acquisition and acquired Percussion’s oil and gas properties in the Delaware Basin for a purchase price of approximately $248.5 million in cash (inclusive of the repayment of Percussion Operating’s indebtedness of approximately $220.0 million) and approximately 6.3 million shares of our common stock, subject to post-closing adjustments. We funded the cash portion of the purchase price with a portion of the proceeds from the Eagle Ford Divestiture where we received approximately $549.3 million in cash upon consummation on July 3, 2023. As part of the Percussion Acquisition, we also assumed Percussion Operating’s existing hedges and transportation contract liabilities and potential earn-out obligations. Pursuant to such assumed earn-out obligations, if the average daily settlement price of WTI crude oil exceeds $60.00 per barrel for 2023, 2024 and 2025 calendar years, we would be required to remit payments of $12.5 million, $25.0 million and $25.0 million, respectively, in January of 2024, 2025 and 2026, respectively. We expect to fund such earn-out obligations with cash provided by operating activities, potential cash received from the Contingent Eagle Ford Consideration, or borrowings under our Credit Facility.

Since December 31, 2022, except as disclosed above, there have been no material changes from what was disclosed in our 2022 Annual Report other than changes to the borrowings under our Credit Facility. See “Note 8 — Borrowings” for additional information.

Critical Accounting Estimates

The preparation of financial statements in conformity with GAAP requires management to make judgments affecting estimates and assumptions for reported amounts of assets, liabilities, revenues and expenses during the periods reported. Certain of such estimates and assumptions are inherently unpredictable and will differ from actual results. Our policies and use of estimates are described in “Note 2 — Summary of Significant Accounting Policies” of the Notes to Consolidated Financial Statements in our 2022 Annual Report. Except as discussed below and in “Note 2 — Summary of Significant Accounting Policies,” of the Notes to Consolidated Financial Statements in this Form 10-Q, there have been no material changes to our critical accounting estimates since December 31, 2022, which are disclosed in “Part II, Item 7A. Management’s Discussion and Analysis of Financial Condition and Results of Operations” of our 2022 Annual Report.

Recast Financial Information for Change in Accounting Principle

In the first quarter of 2023, we voluntarily changed our method of accounting for our oil and gas exploration and development activities from the full cost method to the successful efforts method of accounting. Accordingly, the financial information for prior periods has been recast to reflect retrospective application of the successful efforts method, as prescribed by the FASB ASC 932 “Extractive Activities — Oil and Gas.” See “Note 2 — Summary of Significant Accounting Policies” and “Note 3 — Change in Accounting Principle” for additional discussion.

Impairment of Oil and Natural Gas Properties

We assess our proved oil and gas properties for impairment on an asset group basis whenever events and circumstances indicate that there could be a possible decline in the recoverability of the net book value of such property. We estimate the expected future net cash flows of our proved oil and gas properties and compare these undiscounted cash flows to the net book value of the proved oil and gas properties to determine if the net book value is recoverable. If the net book value exceeds the estimated undiscounted future net cash flows, we will recognize an impairment to reduce the net book value of the proved oil and gas properties to fair value. The factors used to determine fair value include, but are not limited to, estimates of reserves, future commodity prices, future production estimates, estimated future development costs and operating costs, and discount rates, which are based on a weighted average cost of capital. Fair

34

value estimates are based on projected financial information which we believe to be reasonably likely to occur, as of the date that the impairment is measured. See “Note 5 — Acquisitions and Divestitures” for details of the impairment of $406.9 million recorded in the second quarter of 2023 associated with the assets held for sale classification resulting from the agreement to sell all of our interests of Callon (Eagle Ford) LLC to Ridgemar Energy Operating, LLC. There were no impairments of proved oil and gas properties during 2022.

We evaluate significant unproved oil and gas property costs for impairment based on remaining lease term, drilling results, reservoir performance, seismic interpretation or changes in future plans to develop acreage. Unproved oil and gas properties that are not individually significant are aggregated by asset group, and the portion of such costs estimated to be nonproductive prior to lease expiration is amortized over the average holding period. The estimate of what could be nonproductive is based on our historical experience or other information, including current drilling plans and existing geological data.

Income Taxes

Management monitors company-specific, oil and natural gas industry and worldwide economic factors and assesses the likelihood that our net deferred tax assets will be utilized prior to their expiration. As previously disclosed in our 2022 Annual Report, beginning in the second quarter of 2020 and through the fourth quarter of 2022, we maintained a valuation allowance against our net deferred tax assets. Considering all available evidence (both positive and negative), we concluded that it is more likely than not that the deferred tax assets would be realized and released the valuation allowance in the first quarter of 2023. This release resulted in deferred income tax benefit of $0.7 million and $206.1 million for the three and nine months ended September 30, 2023, respectively. As a result of the release of the valuation allowance, we will have no federal deferred income tax expense for fiscal year 2023.

Recently Adopted and Recently Issued Accounting Standards

See “Note 2 — Summary of Significant Accounting Policies” of the Notes to Consolidated Financial Statements in our 2022 Annual Report for discussion.

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 credit risk. We mitigate these risks through a program of risk management including the use of commodity derivative instruments.

Except as set forth below, there have been no material changes to the sources and effects of our market risk since December 31, 2022, which are disclosed in “Part II, Item 7A. Quantitative and Qualitative Disclosures about Market Risk” of our 2022 Annual Report.

Commodity Price Risk

Our revenues are derived from the sale of our oil, natural gas and NGL production. The prices for oil, natural gas and NGLs remain volatile and sometimes experience large fluctuations as a result of relatively small changes in supply, government actions, economic conditions, and weather conditions. We enter into commodity derivative instruments to manage oil, natural gas and NGL price risk, related both to NYMEX benchmark prices and regional basis differentials.

The following table sets forth the fair values of our commodity derivative instruments as of September 30, 2023 as well as the impact on the fair values assuming a 10% increase and decrease in the underlying forward oil and gas price curves as of September 30, 2023:

	Three Months Ended September 30, 2023
	Oil	Natural Gas	NGLs	Total
	(In thousands)
Fair value asset (liability) as of September 30, 2023 (1)	($45,172)	($7,711)	($1,036)	($53,919)
Impact of a 10% increase in forward commodity prices	($85,631)	($9,015)	($1,984)	($96,630)
Impact of a 10% decrease in forward commodity prices	($10,678)	($6,319)	($88)	($17,085)

(1)Spot prices for oil and natural gas were $90.16 and $2.93, respectively, as of September 30, 2023.

Interest Rate Risk

We are subject to market risk exposure related to changes in interest rates on our indebtedness under our Credit Facility. As of September 30, 2023, we had $396.0 million outstanding under the Credit Facility with a weighted average interest rate of 7.50%. An increase or decrease of 1.00% in the interest rate would have a corresponding increase or decrease in our annual interest expense of approximately $4.0 million, based on the balance outstanding as of September 30, 2023. See “Note 8 — Borrowings” for more information on our Credit Facility.

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Item 4. Controls and Procedures

Disclosure Controls and Procedures. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by an issuer in the reports that it files or submits under the Exchange Act is accumulated and communicated to the issuer’s management, including its principal executive and financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure. Our management, with the participation of our principal executive and principal financial officers, performed an evaluation of the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act). Based on this evaluation, our principal executive and principal financial officers have concluded that the Company’s disclosure controls and procedures were effective as of September 30, 2023.

Changes in Internal Control Over Financial Reporting. There were no changes in our internal controls over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the third quarter of 2023 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

Part II.  Other Information

Item 1.  Legal Proceedings

We are a party in various legal proceedings and claims, which arise in the ordinary course of our business. While the outcome of these events cannot be predicted with certainty, we believe that the ultimate resolution of any such actions will not have a material effect on our financial position or results of operations.

Item 1A. Risk Factors

There have been no material changes to the risk factors set forth under the heading “Part I, Item 1A. Risk Factors” included in our 2022 Annual Report. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results.

Item 2.  Unregistered Sales of Equity Securities, Use of Proceeds and Issuer Purchases of Equity Securities

Unregistered Sales of Equity Securities

On July 3, 2023, the Company completed the Percussion Acquisition pursuant to which it acquired Percussion’s oil and gas properties in the Delaware Basin (through the acquisition of all of Percussion Operating’s equity interests) and issued 6,267,385 shares of the Company’s common stock as partial consideration, subject to customary post-closing purchase price adjustments. The shares were issued in reliance upon the exemption from the registration requirements of the Securities Act provided by Section 4(a)(2) of the Securities Act as sales by an issuer not involving any public offering. The issuance of such shares did not involve a public offering for purposes of Section 4(a)(2) because of, among other things, its being made only to the seller in the Percussion Acquisition, such person’s status as an accredited investor and the manner of the issuance, including that the Company did not engage in general solicitation or advertising with regard to the issuance of such shares.

Issuer Repurchases of Equity Securities

Our common stock repurchase activity for the three months ended September 30, 2023 was as follows:

Period	Total Number of Shares Purchased	Average Price Paid Per Share(1)	Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs(2)
July 1 - July 31, 2023	—	$—	—	$300,000,000
August 1 - August 31, 2023	81,574	$36.22	81,574	$297,045,600
September 1 - September 30, 2023	305,145	$39.38	305,145	$285,027,986
Total	386,719	$38.72	386,719

(1)    The average price paid per share excludes any fees, commissions and expenses paid to repurchase stock.

(2)    On May 2, 2023, the Board approved the Share Repurchase Program pursuant to which we are authorized to repurchase up to $300.0 million of our outstanding common stock through the second quarter of 2025. Repurchases under the Share Repurchase Program may be made, from time to time, in amounts and at prices we deem appropriate and will be subject to a variety of factors, including the market price of our common stock, general market and economic conditions and applicable legal requirements. The Share Repurchase Program will expire on June 30, 2025 but may be suspended, modified or discontinued by the Board at any time without prior notice.

Item 3.  Defaults Upon Senior Securities

None.

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Item 4.  Mine Safety Disclosures

Not applicable.

Item 5.  Other Information

None.

Item 6.  Exhibits

The following exhibits are filed as part of this Form 10-Q.

			Incorporated by reference (File No. 001-14039, unless otherwise indicated)
Exhibit Number		Description	Form	Exhibit	Filing Date
2.1	(c)	Membership Interest Purchase Agreement by and among Percussion Petroleum Management II, LLC, Percussion Petroleum Operating II, LLC, Callon Petroleum Operating Company and Callon Petroleum Company dated May 3, 2023.	8-K	10.1	5/8/2023
2.2	(c)	Membership Interest Purchase Agreement by and among Callon Petroleum Operating Company, Callon (Eagle Ford) LLC and Ridgemar Energy Operating, LLC dated May 3, 2023.	8-K	10.2	5/8/2023
3.1		Certificate of Incorporation of the Company, as amended through May 12, 2016	10-Q	3.1	11/3/2016
3.2		Certificate of Amendment to the Certificate of Incorporation of Callon, effective December 20, 2019	8-K	3.1	12/20/2019
3.3		Certificate of Amendment to the Certificate of Incorporation of Callon, effective August 7, 2020	8-K	3.1	8/7/2020
3.4		Certificate of Amendment to the Certificate of Incorporation of Callon, effective May 14, 2021	8-K	3.1	5/14/2021
3.5		Certificate of Amendment to the Certificate of Incorporation of Callon, effective May 25, 2022	8-K	3.1	5/25/2022
3.6		Amended and Restated Bylaws of the Company	10-K	3.2	2/27/2019
4.1		Registration Rights Agreement by and between Callon Petroleum Company and Percussion Petroleum Management II, LLC, dated July 3, 2023	8-K	4.1	7/7/2023
4.2		Second Supplemental Indenture of 6.375% Senior Notes Due 2026, dated July 3, 2023, among Callon Petroleum Company, Callon Permian II, LLC and U.S. Bank Trust Company, National Association, as Trustee	10-Q	4.2	8/2/2023
4.3		First Supplemental Indenture of 8.00% Senior Notes Due 2028, dated July 3, 2023, among Callon Petroleum Company, Callon Permian II, LLC and U.S. Bank Trust Company, National Association, as Trustee	10-Q	4.3	8/2/2023
4.4		First Supplemental Indenture of 7.500% Senior Notes Due 2030, dated July 3, 2023, among Callon Petroleum Company, Callon Permian II, LLC and U.S. Bank Trust Company, National Association, as Trustee	10-Q	4.4	8/2/2023
10.1	(a)	Separation Agreement, dated July 5, 2023, by and between Jeffrey S. Balmer and Callon Petroleum Company
10.2	(a)	Consulting Agreement, dated July 5, 2023, by and between Jeffrey S. Balmer and Callon Petroleum Company
31.1	(a)	Certification of Chief Executive Officer pursuant to Rule 13(a)-14(a)
31.2	(a)	Certification of Chief Financial Officer pursuant to Rule 13(a)-14(a)
32.1	(b)	Section 1350 Certifications of Chief Executive and Financial Officers pursuant to Rule 13(a)-14(b)
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)	Inline XBRL Taxonomy Extension Schema Document
101.CAL	(a)	Inline XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF	(a)	Inline XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB	(a)	Inline XBRL Taxonomy Extension Label Linkbase Document.
101.PRE	(a)	Inline XBRL Taxonomy Extension 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. Pursuant to SEC Release No. 33-8212, this certification will be treated as “accompanying” this report and not “filed” as part of such report for purposes of Section 18 of the Exchange Act or otherwise subject to the liability of Section 18 of the Exchange Act, and this certification will not be deemed to be incorporated by reference into any filing under the Securities Act, except to the extent that the registrant specifically incorporates it by reference.

(c)Certain schedules and similar attachments have been omitted pursuant to Item 601(a)(5) of Regulation S-K. Callon agrees to furnish a supplemental copy of any omitted schedule or attachment to the SEC upon request.

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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.

Callon Petroleum Company

Signature	Title	Date
/s/ Joseph C. Gatto, Jr.	President and	November 1, 2023
Joseph C. Gatto, Jr.	Chief Executive Officer

/s/ Kevin Haggard	Senior Vice President and	November 1, 2023
Kevin Haggard	Chief Financial Officer

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EX-10.1

Exhibit 10.1

SEPARATION AGREEMENT

This Separation Agreement (this “Agreement”) is entered into by and between, and shall inure to the benefit of and be binding upon, the following parties (sometimes collectively referred to herein as the “Parties”):

JEFFREY S. BALMER, hereinafter referred to as “Employee”; and

CALLON PETROLEUM COMPANY, a Delaware corporation (collectively with its subsidiaries, the “Company”).

WI T NE S S E TH:

WHEREAS, Employee previously served as an officer and employee of the

Company;

WHEREAS, the Parties mutually agree that the Employee ceased to serve as an

officer of the Company and its direct and indirect subsidiaries effective as of June 28, 2023, and further agree that the Employee’s employment with the Company ended effective June 28, 2023 (the “Resignation Date”);

WHEREAS, Employee and the Company mutually desire to establish and agree on the terms and conditions of Employee’s separation from service;

NOW, THEREFORE, in consideration of the premises and the mutual agreements, covenants and obligations set forth herein, and other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, and intending to be legally bound, Employee and the Company hereby agree as follows:

Section 1. Separation Benefits and Payments. Following the Resignation Date, all entitlement to compensation and benefits as an employee will cease except as required by applicable law or provided below. Employee will be entitled to (i) a lump-sum payment in an amount equal to Employee’s accrued but unused vacation days and (ii) reimbursement for unpaid business expenses incurred in the ordinary course of business, properly and timely submitted, and consistent with Company policy. In addition, following the Effective Date, Employee shall be entitled to receive the following payments and benefits, to which Employee would not otherwise be entitled, subject to the terms and conditions set forth in this Agreement:

(a)Employee shall receive a payment in the amount of $2,019,500 as Qualified Retirement benefits pursuant to the terms and conditions of his 2021 Cash Performance Units, 2022 “Business Sustainability” Cash Performance Units, and 2022 “Returns” Cash Performance Units.

(b)Company shall transfer to Employee the title to the Company vehicle currently used by Employee within thirty (30) days following the Effective Date.

(c)provided that Employee is otherwise eligible for and timely elects such coverage, Callon shall, at its expense, maintain COBRA continuation coverage for Employee’s and family member’s continued benefit for eighteen (18) months after the Resignation Date for all medical, dental, and vision insurance coverage to which Employee was entitled immediately prior to the Resignation Date; provided, further, that in the event that the Employee obtains other employment that offers group health benefits or begins to receive health benefits through the health benefit plans offered by his spouse’s employer, the Employee agrees to notify the Company promptly following the occurrence of an event (and in no case later than fifteen (15) days following and such events), and Company payment of the COBRA payments shall immediately cease. The

continued coverage under this Section 1(c) shall be provided in a manner that is intended to satisfy an exception to Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”), and therefore not treated as an arrangement providing for nonqualified deferred compensation that is subject to taxation under Code Section 409A.

All payments made or benefits bestowed pursuant to this Section 1 shall be subject to requisite tax withholding and are subject to all the terms and conditions of this Agreement.

Section 2.    Release of Claims.

(a)General Release by Employee. In consideration of the foregoing, which Employee hereby expressly acknowledges as good and sufficient consideration for the releases provided below, Employee hereby unconditionally and irrevocably releases, acquits and forever discharges, to the fullest extent permitted by applicable law, the Company and each of its subsidiaries, divisions, Affiliates, operating companies, predecessors and successors, as well as all of the current and former employees, officers, directors, owners, shareholders, partners, representatives, agents and Affiliates of each of them (collectively, the “Released Parties”), from any and every action, cause of action, complaint, claim, demand, administrative charge, legal right, compensation, promise, agreement, contract, obligation, damages (including consequential, exemplary and punitive damages), liability, cost or expense (including attorney’s fees) that Employee has, may have or may be entitled to from or against any of the Released Parties, whether legal, equitable or administrative, whether known or unknown, which arises directly or indirectly out of, or is based on or related in any way to, Employee’s employment with, compensation and benefits from, termination of employment from, service for or other affiliation with the Company, including any such matter arising from the negligence, gross negligence or reckless, willful or wanton misconduct of any of the Released Parties (together, the “Released Claims”); provided, however, that this release does not apply to, and the Released Claims do not include: (i) any claim for indemnification under the Company’s organizational documents or insurance policies (and subject to the terms and conditions thereof) arising in connection with an action instituted by a third party against the Company or any of its affiliates or Employee, in his capacity as an officer, director, manager, employee, agent or other representative of the Company or any of its affiliates; (ii) any claims for vested benefits under the Company’s 401(k) plan (in accordance with the Company’s books and records for such plan); (iii) any claims relating to Employee’s eligibility to continue participating in health coverage currently available to Employee in accordance with COBRA, subject to the terms, conditions and restrictions of that Act; (iv) any claim arising from any breach of this Agreement or the Consulting Agreement executed commensurate herewith; or (v) any claim for worker’s compensation benefits or any other claim that cannot be waived by a general release. “Affiliate” of any specified person or entity means any other person or entity directly or indirectly Controlling or Controlled by or under direct or indirect common Control with such specified person or entity. “Control,” “Controlling” or “Controlled by” means, when used with respect to any specified person or entity, the power to direct the management and policies of such person or entity, directly or indirectly, whether through the ownership of voting securities.

(b)Release to be Full and Complete; Waiver of Claims, Rights and Benefits. The Parties intend this release to cover any and all such Released Claims, whether they are contract claims, equitable claims, fraud claims, tort claims, discrimination claims, harassment claims, whistleblower or retaliation claims, personal injury claims, constructive or wrongful discharge claims, emotional distress claims, pain and suffering claims, public policy claims, claims for debts, claims for expense reimbursement, wage claims, claims with respect to any other form of compensation, claims for attorneys’ fees, other claims or any combination of the foregoing, and whether they may arise under any

2

employment contract (express or implied), policies, procedures, practices or by any acts or omissions of any of the Released Parties or whether they may arise under any state, local or federal law, statute, ordinance, rule or regulation, including all Texas employment discrimination laws, Chapter 21 of the Texas Labor Code, the Texas Payday Act, all U.S. federal discrimination laws, the U.S. Age Discrimination in Employment Act of 1967, the U.S. Employee Retirement Income Security Act of 1974, Title VII of the U.S. Civil Rights Act of 1964, the U.S. Civil Rights Act of 1991, the U.S. Rehabilitation Act of 1973, the U.S. Americans with Disabilities Act of 1990, the U.S. Equal Pay Act, the U.S. National Labor Relations Act, the U.S. Older Workers Benefit Protection Act, the U.S. Worker Adjustment and Retraining Notification Act, the U.S. Family and Medical Leave Act, the U.S. Sarbanes- Oxley Act of 2002 or common law, without exception. As such, it is expressly acknowledged and agreed that this release is a general release, representing a full and complete disposition and satisfaction of all of the Company’s and any Released Party’s real or alleged legal obligations to Employee except as explicitly provided for herein. Employee understands and agrees, in compliance with any law, statute, ordinance, rule or regulation which requires a specific release of unknown claims or benefits, that this Agreement includes a release of unknown claims, and Employee hereby expressly waives and relinquishes any and all Released Claims and any associated rights or benefits that Employee may have, including any that are unknown to Employee at the time of the execution this Agreement.

(c)Certain Representations of Employee. Employee represents and warrants that: (i) Employee is the sole and lawful owner of all rights, titles and interests in and to all Released Claims; and (ii) Employee has the fully legal right, power, authority and capacity to execute and deliver this Agreement.

(d)Covenant Not to Sue. Employee expressly agrees that neither Employee nor any person acting on Employee’s behalf will file or bring or permit to be filed or brought any lawsuit or other action before any court, agency or other governmental authority for legal or equitable relief against any of the Released Parties involving any of the Released Claims. In the event that such an action is filed against any of the Released Parties, Employee agrees that such Released Parties are entitled to legal and equitable remedies against Employee, including an award of attorney’s fees. However, it is expressly understood and agreed that the foregoing sentence shall not apply to any action filed by Employee that is narrowly limited to seeking a determination as to the validity of this Agreement and enforcement thereof.

(e)Protected Disclosures. Notwithstanding the foregoing or any other provision in this Agreement to the contrary, including any provision in Sections 4, 5 or 6, the Company and Employee further agree that nothing in this Agreement (i) limits Employee’s ability to file a charge or complaint with the EEOC, the NLRB, OSHA, the SEC or any other federal, state or local governmental agency or commission (“Government Agencies”); (ii) limits Employee’s ability to communicate with any Government Agencies or otherwise participate in any investigation or proceeding that may be conducted by any Government Agency, including providing documents or other information and reporting possible violations of law or regulation or other disclosures protected under the whistleblower provisions of applicable law or regulation, without notice to the Company; or (iii) limits Employee’s right to receive an award for information provided to the U.S. Securities and Exchange Commission. Should Employee file a charge or complaint with any Government Agency, or should any governmental entity, agency or commission file a charge, action, complaint or lawsuit against any of the Released Parties based on any Released Claim, Employee agrees not to seek or accept any resulting payment from the Released Parties.

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Section 3.    Return    of    Materials,    Nondisparagement,    Noncompetition, Nonsolicitation, Confidentiality and Other Undertakings.

(a)Return of Materials. On or promptly after the Resignation Date, Employee shall return to the Company with no request being required of the Company: (i) any and all information, property, documents, records, files, reports, memoranda, plans, letters and any other data in Employee’s possession regardless of the medium maintained, held or stored that relate in any way to the business or operations of the Company; and (ii) any credit cards, keys, access cards, calling cards, computer equipment and software, telephone, facsimile or other equipment or property of the Company; provided, however, that Employee shall be entitled to keep his laptop computer and iPad after the Company has had a reasonable opportunity to remove any Confidential Information (as defined below).

(b)Nondisparagement.

(i)Employee shall refrain from making, directly or indirectly, in any public or private communication any criticisms or negative or disparaging comments about the Company or any of the other Released Parties, or about any aspect of the respective businesses, operations, financial results or prospects of the Company, including comments relating to Employee’s separation from employment.

(iii) Notwithstanding the foregoing, it is understood and agreed that nothing in this Section 3(b) is intended to prevent Employee from (x) testifying truthfully in any legal proceeding brought by any governmental authority or other third party or interfere with any obligation to cooperate with or provide information to any government agency or commission, (y) consulting with legal counsel with respect to the interpretation or enforcement of this Agreement, or (z) communicating with his Employee’s spouse and immediate family members.

(c)Noncompetition. Employee agrees that during the term of the Employee’s employment with the Company and for a period of one (1) year following the Resignation Date, he shall not, directly or indirectly, compete with the Company personally or by providing services to any other person, partnership, association, corporation, or other entity that is an Oil and Gas Business in the Permian Basin. As used herein, an “Oil and Gas Business” means owning, managing, acquiring, attempting to acquire, soliciting the acquisition of, operating, controlling, or developing Oil and Gas interests, or engaging in or being connected with, as a principal, owner, officer, director, employee, shareholder, promoter, consultant, contractor, partner, member, joint venture, agent, equity owner or in any other capacity whatsoever, any of the foregoing activities of the oil and gas exploration and production business; provided, however, that Employee shall be permitted to, either directly or indirectly, (i) acquire and own not more than five percent (5%) of any class of securities of any entity listed on a national securities exchange or quoted on the National Association of Securities Dealers Automated Quotation System or over-the-counter; and (ii) perform his obligations under this Agreement or the Consulting Agreement. The Parties agree that the above restrictions on competition are completely severable and independent agreements supported by good and valuable consideration and, as such, shall survive the termination of this Agreement for whatever reason. The Parties further agree that any invalidity or unenforceability of any one or more of such restrictions on competition shall not render invalid or unenforceable any remaining restrictions on competition. Additionally, should a court of competent jurisdiction determine that the scope of any provision of this Section 3(c) is too broad to be enforced as written, the Parties intend that the court reform the provision to such narrower scope as it determines to be reasonable and enforceable.

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(d)Nonsolicitation. During the term of Employee’s employment with the Company and for a period of one (1) year following the Resignation Date, Employee shall not, on his own behalf or on behalf of any other person, partnership, association, corporation, or other entity: (i) directly, indirectly, or through a third party hire or cause to be hired; (ii) directly, indirectly, or through a third party solicit; or (iii) in any manner attempt to influence or induce any employee of the Company or its subsidiaries or Affiliates to leave the employment of the Company or its subsidiaries or Affiliates, nor shall he use or disclose to any person, partnership, association, corporation, or other entity any information obtained concerning the names and addresses the Company’s employees; provided, however, clause 3(d)(i) shall not apply to any such employee who responds to general solicitations through the use of media advertisements, professional search firms, LinkedIn or otherwise. The Parties agree that the above restrictions on hiring and solicitation are completely severable and independent agreements supported by good and valuable consideration and, as such, shall survive the termination of this Agreement for whatever reason. The Parties further agree that any invalidity or unenforceability of any one or more such restrictions on hiring and solicitation shall not render invalid or unenforceable any remaining restrictions on hiring and solicitation. Additionally, should a court of competent jurisdiction determine that the scope of any provision of this Section 3(d) is too broad to be enforced as written, the Parties intend that the court reform the provision to such narrower scope as it determines to be reasonable and enforceable.

(e)Cooperation. Employee agrees to be reasonably available to the Company or its representatives (including their attorneys) to provide information and assistance as requested by the Company. Such information and assistance may include testifying (and preparing to testify) as a witness in any proceeding or otherwise providing information or reasonable assistance to the Company in connection with any investigation, claim or suit. The Employee further agrees not to voluntarily assist any non-governmental adverse party in an action or claim against the Company. Any cooperation required of Employee shall not unreasonably interfere with Employee’s other business endeavors.

(f)Confidentiality and Trade Secrets. The Employee promises not to use in any way or disclose any of the Trade Secrets (as such term is defined in the Callon Executive Change in Control Severance Compensation Plan, effective as of September 21, 2022 (hereinafter the “Callon Executive Change in Control Plan”)) or any other confidential and proprietary information that is not generally known to the public (collectively, and including Trade Secrets, “Confidential Information”) directly or indirectly, after the Resignation Date, except if required in connection with a judicial or administrative proceeding, or if the information becomes public knowledge other than as a result of an unauthorized disclosure by the Employee. All files, records, documents, information, data, and similar items relating to the business of Company, whether prepared by the Employee or otherwise coming into his possession, will remain the exclusive property of Company and may not be removed from the premises of Company under any circumstances without the prior written consent of Company (except as may be reasonably required to render service under the Consulting Agreement), and in any event must be promptly delivered to Company upon termination of the Employee’s employment with Company or, if applicable, the Consulting Agreement. The Employee agrees that upon his receipt of any subpoena, process, or other requests to produce or divulge, directly or indirectly, any Confidential Information to any entity, agency, tribunal, or person, whether received during or after the term of the Employee’s employment with Company, the Employee shall timely notify and promptly deliver a copy of the subpoena, process, or other request to Company. For this purpose, the Employee irrevocably nominates and appoints Company (including any attorney retained by Company), as his true and lawful attorney-in-fact, to act in the Employee’s name,

5

place, and stead to perform any act that the Employee might perform to defend and protect against any disclosure of any Confidential Information. The Parties agree that the above restrictions on confidentiality and disclosure are completely severable and independent agreements supported by good and valuable consideration and, as such, shall survive the termination of this Agreement for whatever reason. The Parties further agree that any invalidity or unenforceability of any one or more of such restrictions on confidentiality and disclosure shall not render invalid or unenforceable any remaining restrictions on confidentiality and disclosure. Additionally, should a court of competent jurisdiction determine that the scope of any provision of this Section 3(f) is too broad to be enforced as written, the Parties intend that the court reform the provision to such narrower scope as it determines to be reasonable and enforceable.

(g)Enforcement of Covenants. Employee acknowledges that the injury that could be suffered by the Company as a result of a breach or threatened breach of the provisions of this Section 3 could be immediate and irreparable and that, because of the difficulty of measuring economic loss of any such breach or threatened breach, an award of monetary damages to the Company for any such breach could be an inadequate remedy. Accordingly, in the event that the Company determines that Employee has breached or attempted to breach or is threatening to breach any provision of this Section 3, in addition to any other remedies at law or in equity that any of the Company may have available to it, it is agreed that the Company shall be entitled to seek, upon application to any court of proper jurisdiction, temporary or permanent restraining orders or injunctions against Employee prohibiting such breach or attempted or threatened breach, without the necessity of: (i) proving immediate or irreparable harm; or (ii) establishing that monetary damages are inadequate or that the Company does not have an adequate remedy at law.

(h)Repayment and Forfeiture. Employee agrees that in the event that Employee breaches or challenges any term of Sections 2 or 3 hereof, and all or any part of Sections 2 or 3 are found invalid or unenforceable for any reason whatsoever by a court of competent jurisdiction or an arbitrator in a proceeding between Employee and Company, in addition to any other remedies at law or in equity the Company may have available to it, the Company shall not be obligated to make any of the payments and may cease to make such payments or to provide for any of the benefits specified in Section 1 hereof, and shall be entitled to recoup from Employee any and all of the value of the payments and benefits provided pursuant to Section 1 hereof that have vested or been paid pursuant to that Section.

Section 4. Entire Agreement; Amendment; Third-Party Beneficiaries. Employee and the Company agree and acknowledge that this Agreement contains and comprises the entire agreement and understanding between the Parties with respect to the subject matter hereof, that no other representation, promise, covenant or agreement of any kind whatsoever has been made to cause either Party to execute this Agreement, that all agreements and understandings between the Parties with respect to the subject matter hereof are embodied and expressed in this Agreement and that this Agreement supersedes all prior agreements, negotiations, discussions, understandings and commitments, written or oral, between the Parties with respect to such subject matter including, without limitation, the Callon Executive Change in Control Plan and the Callon Petroleum Company Executive Severance Pay Plan. The Parties acknowledge and agree that they are executing and delivering a Consulting Agreement of even date herewith, which is not superseded by, by rather is in addition to, this Agreement. The Parties also agree that the terms of this Agreement shall not be amended or changed except in writing and signed by Employee and a duly authorized agent of the Company. The Parties further agree that this Agreement shall be binding on and inure to the benefit of Employee and the Company and the Company’s successors. Except to the extent that each Released Party is expressly intended to be a third-party beneficiary, the provisions of this Agreement shall not confer upon any third party

6

any remedy, claim, liability, reimbursement or other right in excess of those existing without reference to this Agreement.

Section 5. Timing and Consultation with Counsel. Employee acknowledges that (i) he has been given a reasonable period of time, not less than twenty-one (21) days, to consider, and to request changes to, this Agreement and that if he signs this Agreement prior to the end of the 21-day time period he knowingly and voluntarily elected to do so; (ii) he has been advised to discuss the terms of this Agreement with legal counsel of his own choosing; (iii) he was advised that, if accepted, the Agreement could be revoked, in writing, for up to seven (7) days following the date of such acceptance; and (iv) if he revokes this Agreement, his separation from employment as of the Resignation Date shall nevertheless remain effective and he will not be entitled to any of the payments or benefits set forth in Sections 1(a), (b) or (c) hereof.

Section 6. Revocation; Effectiveness. Notwithstanding any other provision in this Agreement to the contrary, Employee may revoke this Agreement, in writing, for up to seven

(7) days following the date of Employee’s execution of this Agreement, by delivering a written notice of Employee’s revocation of this Agreement to the Company. Any such notice of revocation must be received during such period and shall be delivered via email and certified mail to the General Counsel of the Company at One Briarlake Plaza, 2000 W. Sam Houston Parkway S., Suite 2000 Houston, TX 77042 (email address: mecklund@callon.com). If no such revocation occurs, this Agreement will become fully binding, enforceable, and irrevocable on the eighth (8th) day after Employee executes this Agreement and delivers it to the Company, provided that it has also been executed by an officer of the Company and delivered to Employee (the “Effective Date”).

Section 7. Applicable Law; Venue. This Agreement shall be interpreted and construed in accordance with the substantive laws of the State of Texas, without giving effect to any conflicts of laws provisions thereof that would result in the application of the laws of any other jurisdiction. THE EXCLUSIVE VENUE FOR THE RESOLUTION OF ANY DISPUTE RELATING TO THIS AGREEMENT OR EMPLOYEE’S EMPLOYMENT (EXCEPT FOR ANY DISPUTE THAT MAY BE SUBJECTED TO ARBITRATION BY MUTUAL AGREEMENT OF THE PARTIES HERETO AFTER THE DATE HEREOF) SHALL BE IN THE STATE AND FEDERAL COURTS LOCATED IN HARRIS COUNTY, TEXAS AND THE PARTIES HEREBY EXPRESSLY CONSENT TO THE JURISDICTION OF THOSE COURTS.

Section 8. Section 409A; Other Tax Matters. This Agreement is intended to provide payments that are exempt from or compliant with the provisions of Section 409A of the Code and related regulations and Treasury pronouncements (“Section 409A”), and the Agreement shall be interpreted accordingly. Notwithstanding anything herein to the contrary, if on the date of Employee’s separation from service Employee is a “specified employee,” as defined in Section 409A, then all or a portion of any separation payments, or benefits under this Agreement that would be subject to the additional tax provided by Section 409A(a)(1)(B) of the Code if not delayed as required by Section 409A(a)(2)(B)(i) of the Code shall be delayed until the first day of the seventh (7th) month following Employee’s separation from service date (or, if earlier, Employee’s date of death) and shall be paid as a lump sum (without interest) on such date. For purposes of this Agreement, a termination of Employee’s employment must be a “separation from service” for purposes of Section 409A. For purposes of the application of Section 409A, each payment in a series of payments will be deemed a separate payment. Employee acknowledges and agrees that Employee has obtained no advice from the Company, or any of their respective officers, directors, employees, attorneys or other representatives, and that none of such persons or entities have made any representation regarding the tax consequences, if any, of Employee’s receipt of the payments, benefits and other consideration provided for in this Agreement. Employee further acknowledges and agrees that Employee is personally responsible for the payment of all of Employee’s share of federal, state and local taxes

7

that are due, or may be due, for any payments and other consideration received by Employee under this Agreement. Employee agrees to indemnify the Company and hold the Company harmless for any and all taxes, penalties or other assessments that Employee is, or may become, obligated to pay on account of any payments made and other consideration provided to Employee under this Agreement (including, without limitation, any amounts relating to or imposed by the operation of Section 409A of the Code).

Section 9.    Miscellaneous Provisions.

(a)Waivers. Any term or provision of this Agreement may be waived, or the time for its performance may be extended, by the Party entitled to the benefit thereof. Any such waiver shall be validly and sufficiently given for the purposes of this Agreement if, as to either Party, it is in writing signed by such Party or an authorized representative thereof. Failure on the part of the Company or Employee at any time to insist on strict compliance by the other Party with any provisions of this Agreement shall not constitute a waiver of the obligations of either Party in respect thereof, or of either such Party’s right hereunder to require strict compliance therewith in the future. No waiver of any breach of this Agreement shall be deemed to constitute a waiver of any other or subsequent breach.

(b)Severability. If any provision of this Agreement is held to be illegal, invalid or unenforceable under applicable law, that provision shall be severable and this Agreement shall be construed and enforced as if that illegal, invalid or unenforceable provision never comprised a part hereof, and the remaining provisions hereof shall remain in full force and effect and shall not be affected by the illegal, invalid or unenforceable provision, and there shall be added automatically as part of this Agreement a provision as similar in its terms to such illegal, invalid or unenforceable provision as may be possible and be legal, valid and enforceable.

(c)Execution in Counterparts. This Agreement may be executed in any number of counterparts, each of which when so executed and delivered shall be an original, but all such counterparts shall together constitute one and the same instrument.

[Signature page follows]

8

I HAVE READ THE FOREGOING SEPARATION AGREEMENT, I FULLY UNDERSTAND ITS TERMS AND THAT I MAY BE WAIVING SIGNIFICANT LEGAL RIGHTS BY EXECUTING IT, AND I HAVE VOLUNTARILY EXECUTED IT ON THE DATE WRITTEN BELOW, SIGNIFYING THEREBY MY ASSENT TO AND WILLINGNESS TO BE BOUND BY, ITS TERMS:

By:	/s/ Jeffrey S. Balmer
Name:	Jeffrey S. Balmer
Date:	7/5/2023

CALLON PETROLEUM COMPANY

By:	/s/ Joseph C. Gatto, Jr.
Name:	Joseph C. Gatto, Jr.
Title:	President & Chief Executive Officer
Date:	7/5/2023

SIGNATURE PAGE

TO

SEPARATION AGREEMENT

EX-10.2

Exhibit 10.2

CONSULTING AGREEMENT

This Consulting Agreement (this “Agreement”) is made, contingent upon the execution and non-revocation of the separate separation agreement between the parties, as of July 1, 2023 (the “Effective Date”), by and between Callon Petroleum Company, a Delaware corporation (the “Company”) and Jeffrey S. Balmer (the “Consultant”).

WHEREAS, the Company desires to retain the services of the Consultant to provide consulting services to the Company; and

WHEREAS, the Company and the Consultant wish to enter into an agreement to govern the provision of services by the Consultant for the benefit of the Company from and after the Effective Date upon the terms and conditions set forth in this Agreement.

NOW, THEREFORE, in consideration of the mutual covenants and agreements hereinafter set forth, and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the Company and the Consultant hereby agree as follows:

1.Term. This Agreement will be effective as of the Effective Date and will continue until December 31, 2023 (the “Consulting Term”); provided, however, that (1) in the event the Consultant obtains employment or commences or joins a business venture in a principal role, Consultant shall promptly notify the Company and the Consulting Term shall immediately cease no later than the commencement of Consultant’s employment or service to such business venture; (2) Consultant may terminate the Consulting Term at any time by providing the other party with written notice; (3) the Company may terminate the Consulting Term at any time by providing the other party with written notice; provided however that the Company’s obligation to pay the Consulting Fee shall survive such termination and the Consulting Fee shall be paid as provided in Section 3 as if the Consulting Term had continued until December 31, 2023, and (4) Company may terminate this Agreement immediately if Consultant breaches the Agreement.

2.Duties. During the Consulting Term, the Consultant will assist the Company in transitioning the duties of the Chief Operating Officer position and otherwise provide such other consulting services as are reasonably requested by the Company and its affiliates (the “Services”). The Consultant agrees to keep the Company or its designees reasonably informed of the Consultant’s activities relating to this Agreement.

3.Consulting Fees. During the Consulting Term, the Consultant will receive a monthly fee of $50,000 for each full month during the Consulting Term (the “Consulting Fee”), which will be paid monthly in arrears within fourteen (14) days of Company’s receipt of a monthly invoice from Consultant.

4.Reimbursement of Expenses. The Company will reimburse the Consultant for all reasonable business expenses necessary to provide the Services as incurred by the Consultant under this Agreement in accordance with the Company’s policies and procedures applicable to consultants, subject to provision by the Consultant of documentation reasonably satisfactory to the Company.

5.Restrictive Covenants. In consideration for receipt of the Consulting Fee and the provision of Confidential Information (as defined below) to the Consultant, the Consultant agrees to comply with the restrictive covenants set forth below:

(a)Confidentiality.

(i)During the Consulting Term, the Consultant may have access to confidential and proprietary information that is not generally known to the public (“Confidential Information”). The Consultant promises not to use in any way or

disclose Confidential Information, directly or indirectly, either during or after the Consulting Term, except as required in the course of his services with the Company, if required in connection with a judicial or administrative proceeding, or if the information becomes public knowledge other than as a result of an unauthorized disclosure by the Consultant. All files, records, documents, information, data, and similar items relating to the business of Company, whether prepared by the Consultant or otherwise coming into his possession, will remain the exclusive property of Company and may not be removed from the premises of Company under any circumstances without the prior written consent of Company (except in the ordinary course of business during the Consulting Term), and in any event must be promptly delivered to Company upon termination of the Consulting Term. The Consultant agrees that upon his receipt of any subpoena, process, or other requests to produce or divulge, directly or indirectly, any Confidential Information to any entity, agency, tribunal, or person, whether received during or after the Consulting Term, the Consultant shall timely notify and promptly deliver a copy of the subpoena, process, or other request to Company. For this purpose, the Consultant irrevocably nominates and appoints Company (including any attorney retained by Company), as his true and lawful attorney-in-fact, to act in the Consultant’s name, place, and stead to perform any act that the Consultant might perform to defend and protect against any disclosure of any Confidential Information. The parties agree that the above restrictions on confidentiality and disclosure are completely severable and independent agreements supported by good and valuable consideration and, as such, shall survive the termination of this Agreement for whatever reason. The parties further agree that any invalidity or unenforceability of any one or more of such restrictions on confidentiality and disclosure shall not render invalid or unenforceable any remaining restrictions on confidentiality and disclosure. Additionally, should a court of competent jurisdiction determine that the scope of any provision of this Section 5(a)(i) is too broad to be enforced as written, the parties intend that the court reform the provision to such narrower scope as it determines to be reasonable and enforceable.

(ii)In addition, 18 U.S.C. § 1833(b) states: “An individual shall not be held criminally or civilly liable under any Federal or State trade secret law for the disclosure of a trade secret that (A) is made (1) in confidence to a Federal, State, or local government official, either directly or indirectly, or to an attorney; and (2) solely for the purpose of reporting or investigating a suspected violation of law; or (B) is made in a complaint or other document filed in a lawsuit or other proceeding, if such filing is made under seal.” Accordingly, the parties to this Agreement have the right to disclose in confidence trade secrets to Federal, State, and local government officials, or to an attorney, for the sole purpose of reporting or investigating a suspected violation of law. The parties to this Agreement also have the right to disclose trade secrets in a document filed in a lawsuit or other proceeding, but only if the filing is made under seal and protected from public disclosure. Nothing in this Agreement is intended to conflict with 18 U.S.C. § 1833(b) or create liability for disclosures of trade secrets that are expressly allowed by 18 U.S.C. § 1833(b).

(b)Return of Company Property. The Consultant acknowledges that all information, notes, memoranda, specifications, devices, formulas, records, files, lists, drawings, documents, models, equipment, property, computer, software or intellectual property relating to the businesses of the Company and its subsidiaries and affiliates, in whatever form (including electronic), and all copies thereof, that are received or created by the Consultant while engaged hereunder by the Company or its subsidiaries or affiliates (including but not limited to Confidential Information) and inventions are and will remain the property of the Company and

its subsidiaries and affiliates, and the Consultant will immediately return such property to the Company, or at the Company’s election, destroy such property, upon the termination of the Consultant’s engagement hereunder and, in any event, at the Company’s request; provided, however, that Consultant shall be entitled to keep his laptop computer and iPad after the Company has had a reasonable opportunity to remove any Confidential Information (as defined above).

(c)The Consultant further agrees that any property situated on the premises of, and owned by, the Company or its subsidiaries or affiliates, including disks and other storage media, filing cabinets or other work areas, is subject to inspection by the Company’s personnel at any time with or without notice.

(d)Whistleblower Protection. Notwithstanding anything to the contrary contained herein, no provision of this Agreement will be interpreted so as to impede the Consultant (or any other individual) from reporting possible violations of federal law or regulation to any governmental agency or entity, including but not limited to the Department of Justice, the Securities and Exchange Commission, the Congress, and any agency Inspector General, or making other disclosures under the whistleblower provisions of federal law or regulation. The Consultant does not need the prior authorization of the Company to make any such reports or disclosures and the Consultant will not be not required to notify the Company that such reports or disclosures have been made.

6.Limits of Authority. The Consultant has no right or authority, express or implied, to act on behalf of, assume, or create any obligation or responsibility, or otherwise bind, the Company or any of its affiliates in any way. The Consultant shall not make any contrary representation to any third party.

7.Compliance with Policies. As an independent contractor of the Company, the Consultant will perform his duties and responsibilities diligently, loyally, in accordance with the terms of this Agreement, and in compliance with applicable law and all of the Company’s policies, practices, and procedures that apply to the Company’s independent contractors, as they may be adopted or amended from time to time in the Company’s sole discretion.

8.Indemnity. The Consultant agrees to indemnify the Company, and hold it harmless, from and against any and all claims, liabilities, and expenses (including attorneys’ and accountants’ fees, costs, and expenses) resulting from, arising out of, or relating to any uncured breach of this Agreement by Consultant. The Consultant’s indemnification obligations include any losses or expenses incurred by the Company (including reasonable attorneys’ and accountants’ fees, costs, and expenses).

9.WAIVER OF CONSEQUENTIAL DAMAGES. NOTWITHSTANDING ANYTHING CONTAINED IN THIS AGREEMENT TO THE CONTRARY AND REGARDLESS OF THE LEGAL OR EQUITABLE BASIS OF ANY CLAIM, NEITHER PARTY SHALL BE LIABLE TO THE OTHER PARTY FOR, AND EACH PARTY HEREBY RELEASES THE OTHER PARTY FROM, ANY FORM OF DAMAGES OTHER THAN DIRECT DAMAGES, INCLUDING, WITHOUT LIMITATION, SPECIAL, INDIRECT, INCIDENTAL, CONSEQUENTIAL, EXEMPLARY OR PUNITIVE DAMAGES ARISING OUT OF OR RELATING TO THIS AGREEMENT.

10.Remedies. The Consultant understands and agrees that money damages might not be a sufficient remedy for any breach of this Agreement by the Consultant and that the Company could be entitled to equitable relief, including injunction and specific performance, as a remedy for any such breach. Such remedies will not be deemed to be the exclusive remedies for a breach by the Consultant of this Agreement but will be in addition to all other remedies available at law or equity to the Company.

11.Notices. For purposes of this Agreement, notices and all other communications provided for in this Agreement will be in writing and be deemed to have been duly given (a) on the date of delivery, if delivered by hand, (b) on the date of transmission, if delivered by confirmed facsimile or electronic mail, (c) on the first business day following the date of deposit, if delivered by guaranteed overnight delivery service, or (d) on the fourth business day following the date delivered or mailed by United States registered or certified mail, return receipt requested, postage prepaid, addressed as follows:

If to the Consultant:

To the address provided by the Consultant on the signature page attached hereto. If to the Company:

To the Company:    Callon Petroleum Company

One Briarlake Plaza

2000 W. Sam Houston Parkway S., Suite 2000 Houston, TX 77042

Attn:    General Counsel

E-mail:mecklund@callon.com With a copy to: legal@callon.com

or to such other address as either party may have furnished to the other in writing in accordance herewith, except that notices of change of address will only be effective upon receipt.

12.Assignment. The rights and obligations of the Company and the Consultant hereunder will inure to the benefit of and be binding upon their respective successors and permitted assigns. Neither this Agreement nor any rights or interests in this Agreement or created by this Agreement may be assigned or otherwise transferred voluntarily or involuntarily by the Consultant.

13.Representations. The Consultant represents and warrants that the Consultant’s acceptance of this offer, and the Consultant’s performance of the obligations under this Agreement, do not conflict with or violate the terms of (a) any agreement by which the Consultant is bound, including any covenants or obligations to any other employer, entity or person; or (b) any order, rule, law, regulation, or other legal requirement or obligation applicable to the Consultant.

14.Independent Contractor Status. This Agreement will not be construed to create any association, partnership, joint venture, employee, or agency relationship between the Consultant and the Company for any purpose. The Consultant’s relationship to the Company will only be that of an independent contractor and the Consultant will perform the Services pursuant to this Agreement as an independent contractor. The Consultant will not have any right or authority to assume or create any obligation or responsibility, express or implied, on behalf of, or in the name of, the Company, or to bind the Company in any manner. The Consultant will not be entitled to, and will make no claim to, any rights or fringe benefits afforded to employees of the Company, including, without limitation, disability or unemployment insurance, workers’ compensation insurance, pension and retirement benefits, profit-sharing, or rights under any other benefit plan or program applicable to employees of the Company; provided, however, that Consultant and the Company are executing and delivering a Separation Agreement of even date herewith, which is in addition to this Agreement and provides Consultant with certain rights as expressly provided therein. Neither the Company nor any of its affiliates will have responsibility to provide any such

benefits to the Consultant. The Consultant hereby agrees to make the Consultant’s own arrangements for any of such benefits as the Consultant may desire and to indemnify and hold the Company and its affiliates harmless from any and all liabilities or costs related thereto. The manner, means, details or methods by which the Consultant performs the services under this Agreement will be solely within the Consultant’s discretion. The Company makes no representation to Consultant concerning the tax consequences of the payments to be made under this Agreement. The Consultant is responsible for paying all federal, state and local income or business taxes, including estimated taxes, self-employment and any other taxes, fees, additions to tax, interest or penalties that may be assessed or imposed on him, or incurred by him, as a result of the payment of the Consulting Fee, or any other amounts paid by the Company to the Consultant, and agrees to indemnify and hold the Company and its affiliates harmless from any and all liabilities or costs related thereto.

15.Amendment. This Agreement will not be changed or altered, except by an agreement in writing signed by the Consultant and the Company.

16.Governing Law. This Agreement shall be governed by and be construed under the laws of the State of Texas, without regard to conflict of laws principles. Venue of any litigation arising from or relating to this Agreement shall be in a state or federal district court in Harris County, Houston, State of Texas, or United States District Court, Southern District of Texas, Houston Division.

17.Counterparts. This Agreement may be signed in counterparts, each of which will be an original, with the same effect as if the signatures thereto and hereto were upon the same instrument.

[Signature page follows.]

IN WITNESS WHEREOF, the parties have executed this Agreement on the date first written above.

CALLON PETROLEUM COMPANY

By:	/s/ Joseph C. Gatto, Jr.
Name:	Joseph C. Gatto, Jr.
Title:	President & Chief Executive Officer
Date:	7/5/2023

CONSULTANT

By:	/s/ Jeffrey S. Balmer
Name:	Jeffrey S. Balmer
Date:	7/5/2023

SIGNATURE PAGE

TO

CONSULTING AGREEMENT

EX-31.1

Exhibit31.1

CERTIFICATIONS

I, Joseph C. Gatto, Jr., certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of Callon Petroleum Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	November 1, 2023	/s/ Joseph C. Gatto, Jr.
		Joseph C. Gatto, Jr.
		President and Chief Executive Officer
		(Principal executive officer)

EX-31.2

Exhibit31.2

CERTIFICATIONS

I, Kevin Haggard, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q of Callon Petroleum Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	November 1, 2023	/s/ Kevin Haggard
		Kevin Haggard
		Senior Vice President and Chief Financial Officer
		(Principal financial officer)

EX-32.1

Exhibit32.1

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350

In connection with the Quarterly Report on Form 10-Q of Callon Petroleum Company for the quarterly period ended September 30, 2023, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), the undersigned, in the capacities and on the dates indicated below, each hereby certify pursuant to 18 U.S.C. section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that the Report fully complies with requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 and the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	November 1, 2023	/s/ Joseph C. Gatto, Jr.
		Joseph C. Gatto, Jr.
		(Principal executive officer)
Date:	November 1, 2023	/s/ Kevin Haggard
		Kevin Haggard
		(Principal financial officer)

The foregoing certification is being furnished as an exhibit to the Report pursuant to Item 601(b)(32) of Regulation S-K and Section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code) and, accordingly, is not being filed as part of the Report for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and is not incorporated by reference into any filing of the Company, whether made before or after the date hereof, regardless of any general incorporation language in such filing.

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Cover Page - shares	9 Months Ended
	Sep. 30, 2023	Oct. 27, 2023
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2023
Document Transition Report	false
Entity File Number	001-14039
Entity Registrant Name	Callon Petroleum Co
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	64-0844345
Entity Address, Address Line One	One Briarlake Plaza
Entity Address, Address Line Two	2000 W. Sam Houston Parkway S., Suite 2000
Entity Address, City or Town	Houston,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77042
City Area Code	(281)
Local Phone Number	589-5200
Title of 12(b) Security	Common Stock, $0.01 par value
Trading Symbol	CPE
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		67,773,848
Entity Central Index Key	0000928022
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q3
Amendment Flag	false

XML

Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022	[1]
Current assets:
Cash and cash equivalents	$ 3,456	$ 3,395
Accounts receivable, net	262,394	237,128
Fair value of derivatives	1,196	21,332
Other current assets	29,665	35,783
Total current assets	296,711	297,638
Oil and natural gas properties, successful efforts accounting method:
Proved properties, net	4,815,776	4,851,529
Unproved properties	1,287,019	1,225,768
Total oil and natural gas properties, net	6,102,795	6,077,297
Other property and equipment, net	26,398	26,152
Deferred income taxes	199,734	0
Deferred financing costs	14,235	18,822
Fair value of derivatives	21,742	454
Other assets, net	66,908	68,106
Total assets	6,728,523	6,488,469
Current liabilities:
Accounts payable and accrued liabilities	585,529	536,233
Fair value of derivatives	61,189	16,197
Other current liabilities	103,077	150,384
Total current liabilities	749,795	702,814
Long-term debt	1,948,619	2,241,295
Asset retirement obligations	41,290	53,892
Fair value of derivatives	44,807	13,415
Other long-term liabilities	82,954	51,272
Total liabilities	2,867,465	3,062,688
Commitments and contingencies
Stockholders’ equity:
Common stock	678	616
Capital in excess of par value	4,225,183	4,022,194
Accumulated deficit	(364,803)	(597,029)
Total stockholders’ equity	3,861,058	3,425,781	[2]
Total liabilities and stockholders’ equity	$ 6,728,523	$ 6,488,469

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

[2] Financial information for prior periods has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Consolidated Balance Sheets (Parenthetical) - $ / shares	Sep. 30, 2023	Dec. 31, 2022
Statement of Financial Position [Abstract]
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, authorized (in shares)	130,000,000	130,000,000
Common stock, outstanding (in shares)	67,770,721	61,621,518

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Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	[1]	Sep. 30, 2023	Sep. 30, 2022	[1]
Operating Revenues:
Total operating revenues	$ 619,298	$ 835,877		$ 1,741,627	$ 2,526,715
Operating Expenses:
Lease operating	73,525	76,121		225,415	216,389
Production and ad valorem taxes	30,592	43,290		88,019	125,841
Gathering, transportation and processing	27,255	27,575		80,570	71,617
Exploration	3,588	2,942		7,702	7,237
Depreciation, depletion and amortization	138,598	129,895		391,911	359,494
Impairment of oil and gas properties	0	0		406,898	0	[2]
Gain on sale of oil and gas properties	(20,570)	0		(20,570)	0
General and administrative	29,339	24,253		86,905	71,485
Merger, integration and transaction	4,925	0		6,468	769
Total operating expenses	398,370	415,515		1,559,265	1,230,939
Income From Operations	220,928	420,362		182,362	1,295,776
Other (Income) Expenses:
Interest expense	43,149	46,929		136,694	141,020
(Gain) loss on derivative contracts	55,804	(134,850)		24,218	305,098
(Gain) loss on extinguishment of debt	(1,238)	0		(1,238)	42,417
Other (income) expense	3,220	2,861		(3,140)	3,130
Total other (income) expense	100,935	(85,060)		156,534	491,665
Income Before Income Taxes	119,993	505,422		25,828	804,111
Income tax benefit (expense)	(509)	(3,383)		206,398	(6,536)
Net Income	$ 119,484	$ 502,039		$ 232,226	$ 797,575	[2]
Net Income Per Common Share:
Basic (in dollars per share)	$ 1.76	$ 8.14		$ 3.64	$ 12.94
Diluted (in dollars per share)	$ 1.75	$ 8.11		$ 3.63	$ 12.88
Weighted Average Common Shares Outstanding:
Basic (in shares)	67,931	61,703		63,827	61,624
Diluted (in shares)	68,083	61,870		64,016	61,927
Oil
Operating Revenues:
Total operating revenues	$ 438,665	$ 575,852		$ 1,269,996	$ 1,748,913
Natural gas
Operating Revenues:
Total operating revenues	25,045	81,018		63,054	189,907
Natural gas liquids
Operating Revenues:
Total operating revenues	46,489	67,548		130,488	210,696
Sales of purchased oil and gas
Operating Revenues:
Total operating revenues	109,099	111,459		278,089	377,199
Operating Expenses:
Cost of purchased oil and gas	$ 111,118	$ 111,439		$ 285,947	$ 378,107

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

[2] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information

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Consolidated Statements of Stockholders' Equity - USD ($) $ in Thousands		Total		Cumulative Effect, Period of Adoption, Adjustment	Cumulative Effect, Period of Adoption, Adjusted Balance	[1]	Common Stock		Common Stock Cumulative Effect, Period of Adoption, Adjusted Balance	[1]	Capital in Excess of Par	Capital in Excess of Par Cumulative Effect, Period of Adoption, Adjusted Balance	[1]	Accumulated deficit	Accumulated deficit Cumulative Effect, Period of Adoption, Adjustment	Accumulated deficit Cumulative Effect, Period of Adoption, Adjusted Balance	[1]
Beginning balance (in shares) at Dec. 31, 2021							61,371,000		61,371,000
Beginning balance at Dec. 31, 2021		$ 1,865,768		$ 530,732	$ 2,396,500		$ 614		$ 614		$ 4,012,358	$ 4,012,358		$ (2,147,204)	$ 530,732	$ (1,616,472)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)		(7,715)												(7,715)
Restricted stock units (in shares)							6,000
Restricted stock units		2,790									2,790
Common stock issued for Primexx Acquisition (in shares)							117,000
Common stock issued for Primexx Acquisition		6,295					$ 1				6,294
Ending balance (in shares) at Mar. 31, 2022	[1]						61,494,000
Ending balance at Mar. 31, 2022	[1]	2,397,870					$ 615				4,021,442			(1,624,187)
Beginning balance (in shares) at Dec. 31, 2021							61,371,000		61,371,000
Beginning balance at Dec. 31, 2021		1,865,768		$ 530,732	$ 2,396,500		$ 614		$ 614		4,012,358	$ 4,012,358		(2,147,204)	$ 530,732	$ (1,616,472)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	[2],[3]	797,575
Ending balance (in shares) at Sep. 30, 2022	[1]						61,607,000
Ending balance at Sep. 30, 2022	[1]	3,199,960					$ 616				4,018,241			(818,897)
Beginning balance (in shares) at Mar. 31, 2022	[1]						61,494,000
Beginning balance at Mar. 31, 2022	[1]	2,397,870					$ 615				4,021,442			(1,624,187)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)		303,251												303,251
Restricted stock units (in shares)							244,000
Restricted stock units		(1,899)					$ 2				(1,901)
Common stock issued for Percussion Acquisition (in shares)							(22,000)
Common stock issued for Primexx Acquisition		(1,363)									(1,363)
Ending balance (in shares) at Jun. 30, 2022	[1]						61,716,000
Ending balance at Jun. 30, 2022	[1]	2,697,859					$ 617				4,018,178			(1,320,936)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)		502,039	[3]											502,039
Restricted stock units (in shares)							1,000
Restricted stock units		3,893									3,893
Common stock issued for Percussion Acquisition (in shares)							(110,000)
Common stock issued for Primexx Acquisition		(3,831)					$ (1)				(3,830)
Ending balance (in shares) at Sep. 30, 2022	[1]						61,607,000
Ending balance at Sep. 30, 2022	[1]	$ 3,199,960					$ 616				4,018,241			(818,897)
Beginning balance (in shares) at Dec. 31, 2022		61,621,518					61,622,000	[1]
Beginning balance at Dec. 31, 2022	[1]	$ 3,425,781	[4]				$ 616				4,022,194			(597,029)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)		220,638												220,638
Restricted stock units (in shares)							3,000
Restricted stock units		3,339									3,339
Ending balance (in shares) at Mar. 31, 2023							61,625,000
Ending balance at Mar. 31, 2023		$ 3,649,758					$ 616				4,025,533			(376,391)
Beginning balance (in shares) at Dec. 31, 2022		61,621,518					61,622,000	[1]
Beginning balance at Dec. 31, 2022	[1]	$ 3,425,781	[4]				$ 616				4,022,194			(597,029)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)		$ 232,226
Ending balance (in shares) at Sep. 30, 2023		67,770,721					67,771,000
Ending balance at Sep. 30, 2023		$ 3,861,058					$ 678				4,225,183			(364,803)
Beginning balance (in shares) at Mar. 31, 2023							61,625,000
Beginning balance at Mar. 31, 2023		3,649,758					$ 616				4,025,533			(376,391)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)		(107,896)												(107,896)
Restricted stock units (in shares)							263,000
Restricted stock units		810					$ 3				807
Ending balance (in shares) at Jun. 30, 2023							61,888,000
Ending balance at Jun. 30, 2023		3,542,672					$ 619				4,026,340			(484,287)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)		119,484												119,484
Restricted stock units (in shares)							2,000
Restricted stock units		3,881									3,881
Common stock issued for Primexx Acquisition (in shares)							6,267,000
Common stock issued for Primexx Acquisition		210,000					$ 63				209,937
Repurchase and retirement of common stock		$ (14,979)					$ (4)				(14,975)
Repurchase and retirement of common stock (in shares)							(386,000)
Ending balance (in shares) at Sep. 30, 2023		67,770,721					67,771,000
Ending balance at Sep. 30, 2023		$ 3,861,058					$ 678				$ 4,225,183			$ (364,803)

[1] Financial information for prior periods has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

[2] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information

[3] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

[4] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	[1]
Cash flows from operating activities:
Net income	$ 232,226	$ 797,575	[2]
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	391,911	359,494
Impairment of oil and gas properties	406,898	0	[2]
Amortization of non-cash debt related items, net	7,979	9,680
Deferred income tax (benefit) expense	(206,041)	1,110
(Gain) loss on derivative contracts	24,218	305,098
Cash received (paid) for commodity derivative settlements, net	13,274	(433,518)
Gain on extinguishment of debt	(1,238)	42,417
Gain on sale of oil and gas properties	(20,570)	0
Non-cash expense related to share-based awards	9,524	4,427
Other, net	4,563	8,704
Changes in current assets and liabilities:
Accounts receivable	14,219	(52,423)
Other current assets	(13,178)	(12,229)
Accounts payable and accrued liabilities	(69,522)	(8,649)
Net cash provided by operating activities	794,263	1,021,686
Cash flows from investing activities:
Capital expenditures	(751,004)	(648,149)
Acquisition of oil and gas properties	(278,434)	(17,006)
Proceeds from sales of assets	551,446	9,313
Cash paid for settlement of contingent consideration arrangement	0	(19,171)
Other, net	(2,850)	13,497
Net cash used in investing activities	(480,842)	(661,516)
Cash flows from financing activities:
Borrowings on credit facility	2,629,500	2,535,000
Payments on credit facility	(2,736,500)	(2,684,000)
Issuance of 7.5% Senior Notes due 2030	0	600,000
Redemption of 9.0% Second Lien Senior Secured Notes due 2025	0	(339,507)
Payment of deferred financing costs	(560)	(11,623)
Cash paid to repurchase common stock	(14,980)	0
Other, net	(3,582)	1,715
Net cash used in financing activities	(313,360)	(365,702)
Net change in cash and cash equivalents	61	(5,532)
Balance, beginning of period	3,395	9,882
Balance, end of period	3,456	4,350
8.25% Senior Notes due 2025
Cash flows from financing activities:
Redemption of 6.125% Senior Notes due 2024	(187,238)	0
6.125% Senior Note Due 2024
Cash flows from financing activities:
Redemption of 6.125% Senior Notes due 2024	$ 0	$ (467,287)

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information

[2] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Consolidated Statements of Cash Flows (Parenthetical)	Sep. 30, 2023
7.5% Senior Notes due 2030
Debt instrument, interest rate, stated (as a percent)	7.50%
8.25% Senior Notes due 2025
Debt instrument, interest rate, stated (as a percent)	8.25%
6.125% Senior Note Due 2024
Debt instrument, interest rate, stated (as a percent)	6.125%
9.0% Second Lien Senior Secured Notes Due 2025
Debt instrument, interest rate, stated (as a percent)	9.00%

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Description of Business	9 Months Ended
	Sep. 30, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Description of Business	Description of BusinessCallon Petroleum Company is an independent oil and natural gas company focused on the acquisition, exploration and sustainable development of high-quality assets in the Permian Basin in West Texas. As used herein, the “Company,” “Callon,” “we,” “us,” and “our” refer to Callon Petroleum Company and its predecessors and subsidiaries unless the context requires otherwise.

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Summary of Significant Accounting Policies

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

Basis of Presentation

The accompanying unaudited interim consolidated financial statements include the accounts of the Company after elimination of intercompany transactions and balances. These financial statements have been prepared pursuant to the rules and regulations of the SEC and therefore do not include all disclosures required for financial statements prepared in conformity with GAAP. In the opinion of management, these financial statements reflect all normal, recurring adjustments and accruals considered necessary to present fairly, in all material respects, the Company’s interim financial position, results of operations and cash flows. However, the results of operations for the periods presented are not necessarily indicative of the results of operations that may be expected for the full year. Certain reclassifications have been made to prior period amounts to conform to the current period presentation. Such reclassifications did not have a material impact on prior period financial statements.

Significant Accounting Policies

The Company’s significant accounting policies are described in “Note 2 — Summary of Significant Accounting Policies” of the Notes to Consolidated Financial Statements in its 2022 Annual Report and are supplemented by the notes included in this Form 10-Q. The financial statements and related notes included in this Form 10-Q should be read in conjunction with the Company’s 2022 Annual Report.

Recast Financial Information for Change in Accounting Principle

In the first quarter of 2023, the Company voluntarily changed its method of accounting for its oil and gas exploration and development activities from the full cost method to the successful efforts method of accounting. Accordingly, the financial information for prior periods has been recast to reflect retrospective application of the successful efforts method, as prescribed by the FASB Accounting Standards Codification (“ASC”) 932 “Extractive Activities — Oil and Gas.” Although the full cost method of accounting continues to be an accepted alternative, the successful efforts method of accounting is the generally preferred method of the SEC and, because it is more widely used in the industry, the Company expects the change to improve the comparability of its financial statements to its peers. The Company also believes the successful efforts method provides a more representational depiction of assets and operating results and provides for its investments in oil and natural gas properties to be assessed for impairment in accordance with ASC Topic 360 “Property Plant and Equipment,” rather than valuations based on prices and costs prescribed under the full cost method as of the balance sheet date. As required by ASC 250 “Accounting Changes and Error Corrections,” the Company has presented the accumulated effect of the change in accounting principle as a change in the beginning balance of retained earnings (accumulated deficit) of the earliest period presented in the consolidated financial statements. For detailed information regarding the effects of the change to the successful efforts method, see “Note 3 — Change in Accounting Principle.”

Oil and Natural Gas Properties

Proved Oil and Natural Gas Properties. The Company follows the successful efforts method of accounting for its oil and gas properties. Under this method, drilling and completion costs, including lease and well equipment, intangible development costs, and operational support facilities in the field, associated with development wells are capitalized to proved oil and gas properties and are depleted on an asset group basis (properties aggregated based on geographical and geological characteristics) using the units-of-production method based on estimated proved developed oil and gas reserves. The calculation of depletion expense takes into consideration estimated asset retirement costs, net of estimated salvage values.

Proved oil and gas properties are assessed for impairment on an asset group basis whenever events and circumstances indicate that there could be a possible decline in the recoverability of the net book value of such property. The Company estimates the expected

future net cash flows of its proved oil and gas properties and compares these undiscounted cash flows to the net book value of the proved oil and gas properties to determine if the net book value is recoverable. If the net book value exceeds the estimated undiscounted future net cash flows, the Company will recognize an impairment to reduce the net book value of the proved oil and gas properties to fair value. The factors used to determine fair value include, but are not limited to, estimates of reserves, future commodity prices, future production estimates, estimated future development costs and operating costs, and discount rates, which are based on a weighted average cost of capital. See “Note 5 — Acquisitions and Divestitures” for details of the impairment recorded in the second quarter of 2023 associated with the sale of all the Company’s interests of Callon (Eagle Ford) LLC to Ridgemar Energy Operating, LLC.

The partial sale of a proved property within an existing asset group is accounted for as a normal retirement and no net gain or loss on divestiture is recognized as long as the treatment does not significantly alter the units-of-production depletion rate. The sale of a partial interest in an individual proved property is accounted for as a recovery of cost. A net gain or loss on divestiture is recognized in the consolidated statements of operations for all other sales of proved properties.

Unproved Oil and Natural Gas Properties. Unproved oil and gas properties consist of costs incurred in obtaining a mineral interest or a right in a property such as a lease, in addition to broker fees, recording fees and other similar costs. Leasehold costs are classified as unproved until proved reserves are discovered on or otherwise attributed to the property, at which time the related unproved oil and gas property costs are reclassified to proved oil and gas properties and depleted on an asset group basis using the units-of-production method based on estimated total proved oil and gas reserves.

The Company evaluates significant unproved oil and gas property costs for impairment based on remaining lease term, drilling results, reservoir performance, seismic interpretation or changes in future plans to develop acreage. Unproved oil and gas properties that are not individually significant are aggregated by asset group, and the portion of such costs estimated to be nonproductive prior to lease expiration is amortized over the average holding period. The estimate of what could be nonproductive is based on the Company’s historical experience or other information, including current drilling plans and existing geological data. Impairment and amortization of unproved oil and gas properties are recognized as “Impairment of oil and gas properties” in the consolidated statements of operations.

Exploratory. Exploratory costs, including personnel and other internal costs, geological and geophysical expenses and delay rentals for oil and gas leases, are expensed as incurred. Exploratory well costs are initially capitalized pending the determination of whether proved reserves have been discovered. If proved reserves are discovered, exploratory well costs are capitalized as proved oil and gas properties. If proved reserves are not found, exploratory well costs are expensed as dry holes. The application of the successful efforts method of accounting requires management’s judgment to determine the proper designation of wells as either development or exploratory, which will ultimately determine the proper accounting treatment of costs of dry holes.

Capitalized Interest. The Company capitalizes interest on expenditures made in connection with exploration and development projects that meet certain thresholds and are not subject to current amortization. For projects that meet these thresholds, interest is capitalized only for the period that activities are in process to bring the projects to their intended use. Capitalized interest cannot exceed interest expense for the period capitalized. During both the three and nine months ended September 30, 2023 and 2022, the Company did not have any projects that met the thresholds and, therefore, had no capitalized interest.

Share Repurchase Program

The Company repurchases shares of its common stock from time to time under a program authorized by the Board of Directors. The Company retires shares acquired through share repurchases and returns those shares to the status of authorized but unissued. The repurchased and retired shares are recorded as a reduction to “Common stock” and “Capital in excess of par value” in the consolidated balance sheets. See “Note 13 — Stockholders’ Equity” for further discussion.

Recently Issued Accounting Standards

As of September 30, 2023, and through the filing of this report, no new accounting standards have been issued and not yet adopted that are applicable to the Company and that would have a material effect on the Company’s unaudited interim consolidated financial statements and related disclosures.

Subsequent Events

The Company evaluates subsequent events through the date the financial statements are issued. See “Note 17 — Subsequent Events” for further discussion.

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Change in Accounting Principle

9 Months Ended

Sep. 30, 2023

Accounting Changes and Error Corrections [Abstract]

Change in Accounting Principle

Change in Accounting PrincipleIn the first quarter of 2023, the Company voluntarily changed its method of accounting for oil and natural gas exploration and development activities from the full cost method to the successful efforts method. Accordingly, financial information for prior periods has been recast to reflect retrospective application of the successful efforts method. In general, under successful efforts, exploration costs such as exploratory dry holes, exploratory geophysical and geological costs, delay rentals, unproved leasehold impairments and

exploration overhead are expensed as incurred as opposed to being capitalized under the full cost method of accounting. The successful efforts method also provides for the assessment of potential proved oil and gas property impairments by comparing the net book value of proved oil and gas properties to associated estimated undiscounted future net cash flows. If the net book value exceeds the estimated undiscounted future net cash flows, an impairment is recorded to reduce the net book value to fair value. Under the full cost method of accounting, an impairment would be required if the net book value of oil and natural gas properties exceeds a full cost ceiling using an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous 12 months. In addition, gains or losses, if applicable, are recognized more frequently on the divestitures of oil and gas properties under the successful efforts method, as opposed to an adjustment to the net book value of the oil and gas properties under the full cost method.

The “Impairment of oil and gas properties” and “Gain on sale of oil and gas properties” line items presented in the tables below are in connection with the sale of all of the Company’s interests of Callon (Eagle Ford) LLC to Ridgemar Energy Operating, LLC. See “Note 5 — Acquisitions and Divestitures” for additional details.

The following tables present the effects of the change to the successful efforts method in the consolidated balance sheets:

	As of September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Oil and natural gas properties:
Proved properties	$11,191,350	($1,947,545)	$9,243,805
Accumulated depreciation, depletion, amortization and impairments	(6,734,174)	2,306,145	(4,428,029)
Unproved properties	1,807,300	(520,281)	1,287,019
Total oil and gas properties, net	6,264,476	(161,681)	6,102,795
Deferred income taxes	170,001	29,733	199,734
Total assets	$6,860,471	($131,948)	$6,728,523
Stockholders’ equity:
Accumulated deficit	(232,855)	(131,948)	(364,803)
Total stockholders' equity	3,993,006	(131,948)	3,861,058
Total liabilities and stockholders' equity	$6,860,471	($131,948)	$6,728,523

	As of December 31, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Oil and natural gas properties:
Proved properties	$10,367,478	($1,099,343)	$9,268,135
Accumulated depreciation, depletion, amortization and impairments	(6,343,875)	1,927,269	(4,416,606)
Unproved properties	1,711,306	(485,538)	1,225,768
Total oil and gas properties, net	5,734,909	342,388	6,077,297
Total assets	$6,146,081	$342,388	$6,488,469
Deferred income taxes (1)	4,279	2,029	6,308
Stockholders’ equity:
Accumulated deficit	(937,388)	340,359	(597,029)
Total stockholders' equity	3,085,422	340,359	3,425,781
Total liabilities and stockholders' equity	$6,146,081	$342,388	$6,488,469

(1)    Included in “Other long-term liabilities” in the consolidated balance sheets.

The following tables present the effects of the change to the successful efforts method in the consolidated statements of operations:

	Three Months Ended September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands, except per share amounts)
Operating Expenses:
Exploration	$—	$3,588	$3,588
Depreciation, depletion and amortization	138,313	285	138,598
Gain on sale of oil and gas properties	—	(20,570)	(20,570)
General and administrative	22,016	7,323	29,339
Income From Operations	211,554	9,374	220,928
Other Expenses:
Interest expense	14,145	29,004	43,149
Income Before Income Taxes	139,623	(19,630)	119,993
Income tax benefit (expense)	10,663	(11,172)	(509)
Net Income	$150,286	($30,802)	$119,484
Net Income Per Common Share:
Basic	$2.21		$1.76
Diluted	$2.21		$1.75

	Three Months Ended September 30, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands, except per share amounts)
Operating Expenses:
Exploration	$—	$2,942	$2,942
Depreciation, depletion and amortization	122,833	7,062	129,895
General and administrative	14,022	10,231	24,253
Income From Operations	440,597	(20,235)	420,362
Other Expenses:
Interest expense	19,468	27,461	46,929
Income Before Income Taxes	553,118	(47,696)	505,422
Income tax expense	(3,515)	132	(3,383)
Net Income	$549,603	($47,564)	$502,039
Net Income Per Common Share:
Basic	$8.91		$8.14
Diluted	$8.88		$8.11

	Nine Months Ended September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands, except per share amounts)
Operating Expenses:
Exploration	$—	$7,702	$7,702
Depreciation, depletion and amortization	396,348	(4,437)	391,911
Impairment of oil and gas properties	—	406,898	406,898
Gain on sale of oil and gas properties	—	(20,570)	(20,570)
General and administrative	56,305	30,600	86,905
Income From Operations	602,555	(420,193)	182,362
Other Expenses:
Interest expense	52,818	83,876	136,694
Income Before Income Taxes	529,897	(504,069)	25,828
Income tax benefit	174,636	31,762	206,398
Net Income	$704,533	($472,307)	$232,226
Net Income Per Common Share:
Basic	$11.04		$3.64
Diluted	$11.01		$3.63

	Nine Months Ended September 30, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands, except per share amounts)
Operating Expenses:
Exploration	$—	$7,237	$7,237
Depreciation, depletion and amortization	335,221	24,273	359,494
General and administrative	42,052	29,433	71,485
Income From Operations	1,356,719	(60,943)	1,295,776
Other Expenses:
Interest expense	61,717	79,303	141,020
Income Before Income Taxes	944,357	(140,246)	804,111
Income tax expense	(7,008)	472	(6,536)
Net Income	$937,349	($139,774)	$797,575
Net Income Per Common Share:
Basic	$15.21		$12.94
Diluted	$15.14		$12.88

The following tables present the effects of the change to the successful efforts method in the consolidated statements of cash flows:

	Nine Months Ended September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Cash flows from operating activities:
Net income	$704,533	($472,307)	$232,226
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	396,348	(4,437)	391,911
Impairment of oil and gas properties	—	406,898	406,898
Amortization of non-cash debt related items, net	3,064	4,915	7,979
Deferred income tax benefit	(174,279)	(31,762)	(206,041)
Gain on sale of oil and gas properties	—	(20,570)	(20,570)
Non-cash expense related to share-based awards	3,848	5,676	9,524
Net cash provided by operating activities	905,850	(111,587)	794,263
Cash flows from investing activities:
Capital expenditures	(854,889)	103,885	(751,004)
Acquisition of oil and gas properties	(286,136)	7,702	(278,434)
Net cash used in investing activities	(592,429)	111,587	(480,842)
Net change in cash and cash equivalents	61	—	61
Balance, beginning of period	3,395	—	3,395
Balance, end of period	$3,456	$—	$3,456

	Nine Months Ended September 30, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Cash flows from operating activities:
Net income	$937,349	($139,774)	$797,575
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	335,221	24,273	359,494
Amortization of non-cash debt related items, net	4,263	5,417	9,680
Deferred income tax expense	1,626	(516)	1,110
Non-cash expense related to share-based awards	1,055	3,372	4,427
Changes in current assets and liabilities:
Accounts payable and accrued liabilities	(8,693)	44	(8,649)
Net cash provided by operating activities	1,128,870	(107,184)	1,021,686
Cash flows from investing activities:
Capital expenditures	(754,225)	106,076	(648,149)
Acquisition of oil and gas properties	(18,114)	1,108	(17,006)
Net cash used in investing activities	(768,700)	107,184	(661,516)
Net change in cash and cash equivalents	(5,532)	—	(5,532)
Balance, beginning of period	9,882	—	9,882
Balance, end of period	$4,350	$—	$4,350

The following tables present the effects of the change to the successful efforts method in the consolidated statements of stockholders’ equity:

	As of September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Accumulated deficit	($232,855)	($131,948)	($364,803)
Total stockholders’ equity	$3,993,006	($131,948)	$3,861,058

	As of December 31, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Accumulated deficit	($937,388)	$340,359	($597,029)
Total stockholders’ equity	$3,085,422	$340,359	$3,425,781

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Revenue Recognition

9 Months Ended

Sep. 30, 2023

Revenue from Contract with Customer [Abstract]

Revenue Recognition

Revenue Recognition

Revenue from Contracts with Customers

The Company recognizes oil, natural gas, and NGL production revenue at the point in time when control of the product transfers to the purchaser, which differs depending on the applicable contractual terms. Transfer of control also drives the presentation of gathering, transportation and processing expenses in the consolidated statements of operations. See “Note 3 — Revenue Recognition” of the Notes to Consolidated Financial Statements in the 2022 Annual Report for more information regarding the types of contracts under which oil, natural gas, and NGL production revenue is generated.

Oil and Gas Purchase and Sale Arrangements

The Company proactively evaluates development plans and looks to enter into pipeline transportation contracts to mitigate market exposures and help ensure certainty of flow for its oil and gas production, in some cases multiple years in advance of development. Additionally, as the Company looks to optimize its operations and reduce exposures, in certain instances, the Company purchases oil and gas from third parties which is utilized to fulfill portions of its pipeline commitments. Sales of purchased oil and gas represent revenues the Company receives from sales of commodities purchased from a third party. The Company recognizes these revenues and the purchase of the third-party commodities, as well as any costs associated with the purchase, on a gross basis, as the Company acts as a principal in these transactions by assuming control of the purchased commodity before it is transferred to the customer.

Accounts Receivable from Revenues from Contracts with Customers

Net accounts receivable include amounts billed and currently due from revenues from contracts with customers of our oil and natural gas production, which had a balance at September 30, 2023 and December 31, 2022 of $169.3 million and $174.1 million, respectively, and are presented in “Accounts receivable, net” in the consolidated balance sheets.

Prior Period Performance Obligations

The Company records revenue in the month production is delivered to the purchaser. However, settlement statements for sales may not be received for 30 to 90 days after the date production is delivered, and as a result, the Company is required to estimate the amount of production delivered to the purchaser and the price that will be received for the sale of the product. The Company records the differences between estimates and the actual amounts received for product sales in the month that payment is received from the purchaser. The Company has existing internal controls for its revenue estimation process and related accruals, and any identified differences between its revenue estimates and actual revenue received historically have not been significant.

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Acquisitions and Divestitures

9 Months Ended

Sep. 30, 2023

Business Combination and Asset Acquisition [Abstract]

Acquisitions and Divestitures

Acquisitions and Divestitures

Eagle Ford Divestiture

On May 3, 2023, the Company entered into an agreement with Ridgemar Energy Operating, LLC (“Ridgemar”) for the sale of all its oil and gas properties in the Eagle Ford (the “Eagle Ford Divestiture”) for consideration of $655.0 million in cash, subject to customary purchase price adjustments, as well as contingent consideration where the Company could receive up to $45.0 million if the WTI price of oil exceeds certain thresholds in 2024 (“Contingent Eagle Ford Consideration”). See “Note 9 — Derivative Instruments and Hedging Activities” for further discussion of the Contingent Eagle Ford Consideration. Upon signing, Ridgemar paid approximately $49.1 million as a deposit into a third-party escrow account. The transaction was structured as the acquisition by Ridgemar of 100% of the limited liability company interests of the Company’s wholly owned subsidiary, Callon (Eagle Ford) LLC.

During the second quarter of 2023, the Company classified the assets and liabilities associated with the Eagle Ford Divestiture as held for sale, and recorded an impairment of $406.9 million against properties associated with the Eagle Ford Divestiture as the fair value less cost to sell was less than the carrying amount of the net assets. On July 3, 2023, the Company closed the Eagle Ford Divestiture. The Eagle Ford Divestiture has an adjusted purchase price of approximately $549.3 million in cash, inclusive of the deposit paid at signing, subject to customary post-closing purchase price adjustments. As a result, the Company recorded a gain on sale of assets of $20.6 million.

Percussion Acquisition

On May 3, 2023, the Company entered into an agreement (the “Percussion Agreement”) with Percussion Petroleum Management II, LLC (“Percussion”) for the purchase of its oil and gas properties in the Delaware Basin (the “Percussion Acquisition”) for

consideration of $475.0 million, which consisted of $255.0 million in cash, inclusive of the repayment of Percussion’s indebtedness of approximately $220.0 million, and $210.0 million of shares of the Company’s common stock, subject to customary purchase price adjustments. Upon signing, the Company paid $36.0 million as a deposit into a third-party escrow account. The transaction was structured as the acquisition by Callon Petroleum Operating Company of 100% of the limited liability company interests of Percussion’s wholly owned subsidiary, Percussion Petroleum Operating II, LLC (“Percussion Operating”).

On July 3, 2023, the Company closed the Percussion Acquisition for an adjusted purchase price of approximately $248.5 million in cash, inclusive of the deposit paid at signing and the repayment of Percussion Operating’s indebtedness of approximately $220.0 million, and approximately 6.3 million shares of the Company’s common stock for total consideration of $458.5 million, subject to customary post-closing purchase price adjustments. The Company funded the cash portion of the total consideration with proceeds from the Eagle Ford Divestiture. Additionally, the Company assumed Percussion Operating’s (as defined below) existing hedges and transportation contract liabilities, and could have to pay up to $62.5 million if the WTI price of oil exceeds certain thresholds in 2023, 2024, and 2025 (“Percussion Earn-Out Obligation”).

The Percussion Acquisition was accounted for as a business combination; therefore, the purchase price was allocated to the assets acquired and the liabilities assumed based on their estimated acquisition date fair values with information available at that time. A combination of a discounted cash flow model and market data was used by a third-party specialist in determining the fair value of the oil and gas properties. Significant inputs into the calculation included future commodity prices, estimated volumes of oil and gas reserves, expectations for timing and amount of future development and operating costs, future plugging and abandonment costs and a risk adjusted discount rate. Certain data necessary to complete the purchase price allocation is not yet available. The Company expects to complete the purchase price allocation during the 12-month period following the acquisition date.

The following table sets forth the Company’s preliminary allocation of the total estimated consideration of $458.5 million to the assets acquired and liabilities assumed as of the acquisition date.

	Preliminary Purchase Price Allocation
	(In thousands)
Assets:
Accounts receivable, net	$30,135
Proved properties, net	491,367
Unproved properties	52,590
Total assets acquired	$574,092
Liabilities:
Accounts payable and accrued liabilities	$42,585
Fair value of derivatives - current	20,660
Other current liabilities	11,471
Asset retirement obligations	2,323
Fair value of derivatives - long-term	27,979
Other long-term liabilities	10,619
Total liabilities assumed	$115,637
Total consideration	$458,455

Approximately $57.8 million of revenues and $16.3 million of direct operating expenses attributed to the assets acquired in the Percussion Acquisition are included in the Company’s consolidated statements of operations for the period from the closing date on July 3, 2023 through September 30, 2023.

Pro Forma Operating Results (Unaudited). The following unaudited pro forma combined condensed financial data for the three and nine months ended September 30, 2023 and 2022 was derived from the historical financial statements of the Company and gives effect to the Percussion Acquisition, as if it had occurred on January 1, 2022. The below information reflects pro forma adjustments for the issuance of the Company’s common stock, as well as pro forma adjustments based on available information and certain assumptions that the Company believes provide a reasonable basis for reflecting the significant pro forma effects directly attributable to the Percussion Acquisition.

The pro forma consolidated statements of operations data has been included for comparative purposes only and is not necessarily indicative of the results that might have occurred had the Percussion Acquisition taken place on January 1, 2022 and is not intended to be a projection of future results.

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022*	2023	2022*
	(In thousands, except per share amounts)
Revenues	$619,298	$928,218	$1,879,442	$2,815,342
Income from operations	220,928	480,459	252,809	1,490,205
Net income	119,484	708,355	360,850	856,610
Basic earnings per common share	$1.76	$10.42	$5.65	$12.62
Diluted earnings per common share	$1.75	$10.40	$5.64	$12.56

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Property and Equipment, Net

9 Months Ended

Sep. 30, 2023

Property, Plant and Equipment [Abstract]

Property and Equipment, Net

Property and Equipment, Net

As of September 30, 2023 and December 31, 2022, total property and equipment, net consisted of the following:

	September 30, 2023	December 31, 2022*
Oil and natural gas properties, successful efforts accounting method	(In thousands)
Proved properties	$9,243,805	$9,268,135
Accumulated depreciation, depletion, amortization and impairments	(4,428,029)	(4,416,606)
Proved properties, net	4,815,776	4,851,529
Unproved properties	1,287,019	1,225,768
Total oil and natural gas properties, net	$6,102,795	$6,077,297
Other property and equipment	$40,243	$40,530
Accumulated depreciation	(13,845)	(14,378)
Other property and equipment, net	$26,398	$26,152

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Earnings Per Share

9 Months Ended

Sep. 30, 2023

Earnings Per Share [Abstract]

Earnings Per Share

Earnings Per ShareBasic earnings per share is computed by dividing net income by the weighted average number of shares outstanding for the periods presented. The calculation of diluted earnings per share includes the potential dilutive impact of non-vested restricted stock units outstanding during the periods presented, as calculated using the treasury stock method, unless their effect is anti-dilutive.

The following table sets forth the computation of basic and diluted earnings per share:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022*	2023	2022*
	(In thousands, except per share amounts)
Net Income	$119,484	$502,039	$232,226	$797,575
Basic weighted average common shares outstanding	67,931	61,703	63,827	61,624
Dilutive impact of restricted stock units	152	167	189	303
Diluted weighted average common shares outstanding	68,083	61,870	64,016	61,927
Net Income Per Common Share
Basic	$1.76	$8.14	$3.64	$12.94
Diluted	$1.75	$8.11	$3.63	$12.88
Restricted stock units (1)	54	100	75	28
Warrants (1)	481	481	481	416

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

(1)    Shares excluded from the diluted earnings per share calculation because their effect would be anti-dilutive.

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Borrowings

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Borrowings

Borrowings

The Company’s borrowings consisted of the following:

	September 30, 2023	December 31, 2022
	(In thousands)
8.25% Senior Notes due 2025	$—	$187,238
6.375% Senior Notes due 2026	320,783	320,783
Senior Secured Revolving Credit Facility due 2027	396,000	503,000
8.0% Senior Notes due 2028	650,000	650,000
7.5% Senior Notes due 2030	600,000	600,000
Total principal outstanding	1,966,783	2,261,021
Unamortized premium on 8.25% Senior Notes	—	1,715
Unamortized deferred financing costs for Senior Notes	(18,164)	(21,441)
Long-term debt (1)	$1,948,619	$2,241,295

(1)    Excludes unamortized deferred financing costs related to the Company’s senior secured revolving credit facility of $14.2 million and $18.8 million as of September 30, 2023 and December 31, 2022, respectively, which are classified in “Deferred financing costs” in the consolidated balance sheets.

Senior Secured Revolving Credit Facility

The Company has a senior secured revolving credit facility with a syndicate of lenders (the “Credit Facility”) that, as of September 30, 2023, had a maximum credit amount of $5.0 billion, a borrowing base of $2.0 billion and an elected commitment amount of $1.5 billion, with borrowings outstanding of $396.0 million at a weighted-average interest rate of 7.50%, and letters of credit outstanding of $21.4 million. The credit agreement governing the Credit Facility (the “Credit Agreement”) provides for interest-only payments until October 19, 2027 when the Credit Agreement matures and any outstanding borrowings are due.

Borrowings outstanding under the Credit Agreement bear interest at the Company’s option at either (i) a base rate for a base rate loan plus a margin between 0.75% to 1.75%, where the base rate is defined as the greatest of the prime rate, the federal funds rate plus 0.50%, and the SOFR plus 0.1% (“Adjusted SOFR”) for a one month period plus 1.00%, or (ii) an Adjusted SOFR plus a margin between 1.75% to 2.75%. The Company also incurs commitment fees at rates ranging between 0.375% to 0.500% on the unused portion of lender commitments, which are included in “Interest expense” in the consolidated statements of operations.

The borrowing base under the Credit Agreement is subject to regular redeterminations in the spring and fall of each year, as well as special redeterminations described in the Credit Agreement, which in each case may reduce the amount of the borrowing base. On October 31, 2023, as part of the Company’s fall 2023 redetermination, the borrowing base of $2.0 billion and elected commitment amount of $1.5 billion were reaffirmed.

Redemption of 8.25% Senior Notes due 2025

On August 2, 2023, the Company used borrowings under the Credit Facility to redeem all $187.2 million of its outstanding 8.25% Senior Notes due 2025 (“8.25% Senior Notes”). The Company recognized a gain on extinguishment of debt of approximately $1.2 million in its consolidated statements of operations, which primarily related to the remaining unamortized premium.

Covenants

The Credit Agreement and the indentures governing the 6.375% Senior Notes due 2026, the 8.0% Senior Notes due 2028, and the 7.5% Senior Notes due 2030 (collectively, the “Senior Notes”) limit the Company and certain of its subsidiaries with respect to the amount of additional indebtedness, liens, dividends and other payments to shareholders, repurchases or redemptions of the Company’s common stock, redemptions of senior notes, investments, acquisitions, mergers, asset dispositions, transactions with affiliates, hedging transactions and other matters, along with maintenance of certain financial ratios.

Under the Credit Agreement, the Company must maintain the following financial covenants determined as of the last day of the quarter: (1) a Leverage Ratio (as defined in the Credit Agreement) of no more than 3.50 to 1.00 and (2) a Current Ratio (as defined in the Credit Agreement) of not less than 1.00 to 1.00. The Company was in compliance with these covenants at September 30, 2023.

The Credit Agreement and indentures are subject to customary events of default. If an event of default occurs and is continuing, the holders or lenders may elect to accelerate amounts due (except in the case of a bankruptcy event of default, in which case such amounts will automatically become due and payable).

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Derivative Instruments and Hedging Activities

9 Months Ended

Sep. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities

Objectives and Strategies for Using Derivative Instruments

The Company is exposed to fluctuations in oil, natural gas and NGL prices received for its production. Consequently, the Company believes it is prudent to manage the variability in cash flows on a portion of its oil, natural gas and NGL production. The Company utilizes a mix of collars, swaps, put and call options, and basis differential swaps to manage fluctuations in cash flows resulting from changes in commodity prices. The Company does not use these instruments for speculative or trading purposes.

Counterparty Risk and Offsetting

The Company typically has numerous commodity derivative instruments outstanding with a counterparty that were executed at various dates, for various contract types, commodities and time periods. This often results in both commodity derivative asset and liability positions with that counterparty. The Company nets its commodity derivative instrument fair values executed with the same counterparty to a single asset or liability pursuant to International Swap Dealers Association Master Agreements, which provide for net settlement over the term of the contract and in the event of default or termination of the contract. In general, if a party to a derivative transaction incurs an event of default, as defined in the applicable agreement, the other party will have the right to demand the posting of collateral, demand a cash payment transfer or terminate the arrangement.

The Company strives to minimize its credit exposure to any individual counterparty and, as such, the Company has outstanding commodity derivative instruments with nine counterparties as of September 30, 2023. All of the counterparties to the Company’s commodity derivative instruments are also lenders under the Company’s Credit Facility. Therefore, each of the Company’s counterparties allow the Company to satisfy any need for margin obligations associated with commodity derivative instruments where the Company is in a net liability position with the collateral securing the Credit Facility, thus eliminating the need for independent collateral posting.

Because each of the Company’s counterparties has an investment grade credit rating, the Company believes it does not have significant credit risk and accordingly does not currently require its counterparties to post collateral to support the net asset positions of its commodity derivative instruments. Although the Company does not currently anticipate nonperformance from its counterparties, it continually monitors the credit ratings of each counterparty.

While the Company monitors counterparty creditworthiness on an ongoing basis, it cannot predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, the Company may be limited in its ability to mitigate an increase in counterparty credit risk. Should one of these counterparties not perform, the Company may not realize the benefit of some of its derivative instruments under lower commodity prices while continuing to be obligated under higher commodity price contracts subject to any right of offset under the agreements. Counterparty credit risk is considered when determining the fair value of a derivative instrument. See “Note 10 — Fair Value Measurements” for further discussion.

Contingent Consideration Arrangements

Percussion Earn-Out Obligation. As a result of the Percussion Acquisition, the Company assumed an earn-out obligation from Percussion Operating, where the Company could be required to pay up to $62.5 million in the aggregate if the average daily settlement price of WTI crude oil exceeds $60.00 per barrel for each of the 2023, 2024, and 2025 calendar years.

Contingent Eagle Ford Consideration. As a result of the Eagle Ford Divestiture, the Company received a contingent consideration arrangement from Ridgemar. The Company could receive up to $45.0 million if the average daily settlement price of WTI crude oil for 2024 is at least $80.00 per barrel. If the average daily settlement price of WTI crude oil for 2024 is less than $80.00 per barrel but at least $75.00 per barrel, then the Company would receive $20.0 million.

The Company determined that the Percussion Earn-Out Obligation and Contingent Eagle Ford Consideration receipt were not clearly and closely related to the Percussion Acquisition and Eagle Ford Divestiture membership interest purchase agreements, and therefore bifurcated these embedded features and recorded these derivatives at their acquisition date fair value and divestiture date fair value of $34.9 million and $10.9 million, respectively, in the consolidated financial statements. As of September 30, 2023, the estimated fair values of the Percussion Earn-Out Obligation and Contingent Eagle Ford Consideration were $46.4 million and $21.7 million, respectively, and are presented in “Fair value of derivatives” in the consolidated balance sheets.

Financial Statement Presentation and Settlements

The Company records its derivative instruments at fair value in the consolidated balance sheets and records changes in fair value, as well as settlements during the period, as “(Gain) loss on derivative contracts” in the consolidated statements of operations. The Company presents the fair value of derivative contracts on a net basis in the consolidated balance sheets as they are subject to master netting arrangements. The following presents the impact of this presentation to the Company’s recognized assets and liabilities for the periods indicated:

	As of September 30, 2023
	Presented without		As Presented with
	Effects of Netting	Effects of Netting	Effects of Netting
	(In thousands)
Derivative Assets
Commodity derivative instruments	$9,792	($8,596)	$1,196
Fair value of derivatives - current	$9,792	($8,596)	$1,196
Commodity derivative instruments	$4,270	($4,208)	$62
Contingent consideration arrangements	21,680	—	21,680
Fair value of derivatives - non-current	$25,950	($4,208)	$21,742
Derivative Liabilities
Commodity derivative instruments	($57,575)	$8,596	($48,979)
Contingent consideration arrangements	(12,210)	—	(12,210)
Fair value of derivatives - current	($69,785)	$8,596	($61,189)
Commodity derivative instruments	($14,805)	$4,208	($10,597)
Contingent consideration arrangements	(34,210)	—	(34,210)
Fair value of derivatives - non-current	($49,015)	$4,208	($44,807)

	As of December 31, 2022
	Presented without		As Presented with
	Effects of Netting	Effects of Netting	Effects of Netting
	(In thousands)
Derivative Assets
Fair value of derivatives - current	$51,984	($30,652)	$21,332
Fair value of derivatives - non-current	$1,343	($889)	$454
Derivative Liabilities
Fair value of derivatives - current	($46,849)	$30,652	($16,197)
Fair value of derivatives - non-current	($14,304)	$889	($13,415)

The components of “(Gain) loss on derivative contracts” are as follows for the respective periods:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022	2023	2022
	(In thousands)
(Gain) loss on oil derivatives	$54,446	($157,731)	$18,165	$243,527
(Gain) loss on natural gas derivatives	(2,315)	22,881	2,380	56,800
Loss on NGL derivatives	2,933	—	2,933	4,771
Loss on contingent consideration arrangements	740	—	740	—
(Gain) loss on derivative contracts	$55,804	($134,850)	$24,218	$305,098

The components of “Cash received (paid) for commodity derivative settlements, net” and “Cash received (paid) for settlements of contingent consideration arrangements, net” are as follows for the respective periods:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022	2023	2022
	(In thousands)
Cash flows from operating activities
Cash received (paid) on oil derivatives	$1,680	($117,024)	($4,450)	($374,711)
Cash received (paid) on natural gas derivatives	(560)	(28,572)	17,816	(55,024)
Cash paid on NGL derivatives	(92)	—	(92)	(3,783)
Cash received (paid) for commodity derivative settlements, net	$1,028	($145,596)	$13,274	($433,518)
Cash received for settlements of contingent consideration arrangements, net (1)	$—	$—	$—	$6,492
Cash flows from investing activities
Cash paid for settlement of contingent consideration arrangement (1)	$—	$—	$—	($19,171)
Cash flows from financing activities
Cash received for settlement of contingent consideration arrangement (1)	$—	$—	$—	$8,512

(1)    See “Note 8 — Derivative Instruments and Hedging Activities” of the Notes to Consolidated Financial Statements in our 2022 Annual Report for discussion of the contingent consideration arrangements.

Derivative Positions

Listed in the tables below are the outstanding oil, natural gas, and NGL derivative contracts as of September 30, 2023:

	For the Remainder	For the Full Year
Oil Contracts (WTI)	2023	2024
Swap Contracts
Total volume (Bbls)	—	1,076,300
Weighted average price per Bbl	$—	$81.66
Collar Contracts (Three-Way Collars)
Total volume (Bbls)	541,528	3,963,025
Weighted average price per Bbl
Ceiling (short call)	$70.95	$78.86
Floor (long put)	$55.00	$58.16
Floor (short put)	$45.00	$48.16
Collar Contracts (Two-Way Collars)
Total volume (Bbls)	993,455	—
Weighted average price per Bbl
Ceiling (short call)	$87.20	$—
Floor (long put)	$72.04	$—
CMA Roll Swap Contracts
Total volume (Bbls)	838,828	—
Weighted average price per Bbl	$0.30	$—

	For the Remainder	For the Full Year
Natural Gas Contracts (Henry Hub)	2023	2024
Swap Contracts
Total volume (MMBtu)	620,000	—
Weighted average price per MMBtu	$3.00	$—
Collar Contracts
Total volume (MMBtu)	2,201,104	8,598,557
Weighted average price per MMBtu
Ceiling (short call)	$5.37	$3.89
Floor (long put)	$3.14	$3.00
Natural Gas Contracts (Waha Basis Differential)
Swap Contracts
Total volume (MMBtu)	2,460,000	7,320,000
Weighted average price per MMBtu	($1.49)	($1.06)
Natural Gas Contracts (HSC Basis Differential)
Swap Contracts
Total volume (MMBtu)	2,760,000	14,640,000
Weighted average price per MMBtu	($0.29)	($0.42)

	For the Remainder	For the Full Year
NGL Contracts (Mont Belvieu Natural Gasoline)	2023	2024
Swap Contracts
Total volume (Bbls)	43,105	—
Weighted average price per Bbl	$56.38	$—
NGL Contracts (Mont Belvieu Propane)
Swap Contracts
Total volume (Bbls)	35,754	—
Weighted average price per Bbl	$31.27	$—
NGL Contracts (Mont Belvieu Purity Ethane)
Swap Contracts
Total volume (Bbls)	35,095	—
Weighted average price per Bbl	$9.54	$—
NGL Contracts (Mont Belvieu Normal Butane)
Swap Contracts
Total volume (Bbls)	33,470	72,105
Weighted average price per Bbl	$35.56	$33.18
NGL Contracts (Mont Belvieu Isobutane)
Swap Contracts
Total volume (Bbls)	10,967	23,462
Weighted average price per Bbl	$35.42	$33.18

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Fair Value Measurements

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

Accounting guidelines for measuring fair value establish a three-level valuation hierarchy for disclosure of fair value measurements. The valuation hierarchy categorizes assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. The three levels are defined as follows:

Level 1 – Observable inputs such as quoted prices in active markets at the measurement date for identical, unrestricted assets or liabilities.

Level 2 – Other inputs that are observable directly or indirectly, such as quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability.

Level 3 – Unobservable inputs for which there is little or no market data and for which the Company makes its own assumptions about how market participants would price the assets and liabilities.

Fair Value of Financial Instruments

Cash, Cash Equivalents, and Restricted Investments. The carrying amounts for these instruments approximate fair value due to the short-term nature or maturity of the instruments.

Debt. The carrying amount of borrowings outstanding under the Credit Facility approximates fair value as the borrowings bear interest at variable rates and are reflective of market rates. The following table presents the principal amounts of the Senior Notes with the fair values measured using quoted secondary market trading prices which are designated as Level 2 within the valuation hierarchy.

	September 30, 2023		December 31, 2022
	Principal Amount	Fair Value	Principal Amount	Fair Value
	(In thousands)
8.25% Senior Notes	$—	$—	$187,238	$186,719
6.375% Senior Notes	320,783	314,634	320,783	301,732
8.0% Senior Notes	650,000	650,800	650,000	616,935
7.5% Senior Notes	600,000	581,754	600,000	550,812
Total	$1,570,783	$1,547,188	$1,758,021	$1,656,198

Assets and Liabilities Measured at Fair Value on a Recurring Basis

Certain assets and liabilities are reported at fair value on a recurring basis in the consolidated balance sheets. The following methods and assumptions were used to estimate fair value:

Commodity Derivative Instruments. The fair value of commodity derivative instruments is derived using a third-party income approach valuation model that utilizes market-corroborated inputs that are observable over the term of the commodity derivative

contract. The Company’s fair value calculations also incorporate an estimate of the counterparties’ default risk for commodity derivative assets and an estimate of the Company’s default risk for commodity derivative liabilities. As the inputs in the model are substantially observable over the term of the commodity derivative contract and as there is a wide availability of quoted market prices for similar commodity derivative contracts, the Company designates its commodity derivative instruments as Level 2 within the fair value hierarchy. See “Note 9 — Derivative Instruments and Hedging Activities” for further discussion.

Contingent Consideration Arrangements - Embedded Derivative Financial Instruments. The embedded options within the contingent consideration arrangements are considered financial instruments under ASC 815. The Company engages a third-party valuation specialist using an option pricing model approach to measure the fair value of the embedded options on a recurring basis. The valuation includes significant inputs such as forward oil price curves, time to expiration, and implied volatility. The model provides for the probability that the specified pricing thresholds would be met for each settlement period, estimates undiscounted payouts, and risk adjusts for the discount rates inclusive of adjustments for each of the counterparty’s credit quality. As these inputs are substantially observable for the full term of the contingent consideration arrangements, the inputs are considered Level 2 inputs within the fair value hierarchy. See “Note 9 - Derivative Instruments and Hedging Activities” for further discussion.

The following tables present the Company’s assets and liabilities measured at fair value on a recurring basis as of September 30, 2023 and December 31, 2022:

	September 30, 2023
	Level 1	Level 2	Level 3
	(In thousands)
Derivative Assets
Commodity derivative instruments	$—	$1,258	$—
Contingent consideration arrangements	—	21,680	—
Total net assets	$—	$22,938	$—
Derivative Liabilities
Commodity derivative instruments	$—	($59,576)	$—
Contingent consideration arrangements	—	(46,420)	—
Total net liabilities	$—	($105,996)	$—
	December 31, 2022
	Level 1	Level 2	Level 3
	(In thousands)
Commodity derivative assets	$—	$21,786	$—
Commodity derivative liabilities	$—	($29,612)	$—

There were no transfers between any of the fair value levels during any period presented.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

Acquisitions. The fair value of assets acquired and liabilities assumed are measured as of the acquisition date by a third-party valuation specialist using a combination of income and market approaches, which are not observable in the market and are therefore designated as Level 3 inputs. Significant inputs include expected discounted future cash flows from estimated reserve quantities, estimates for timing and costs to produce and develop reserves, oil and natural gas forward prices, and a risk adjusted discount rate. See “Note 5 –Acquisitions and Divestitures” for additional discussion.

Asset Retirement Obligations. The Company measures the fair value of asset retirement obligations as of the date a well begins drilling or when production equipment and facilities are installed using a discounted cash flow model based on inputs that are not observable in the market and that, therefore, are designated as Level 3 within the valuation hierarchy. Significant inputs to the fair value measurement of asset retirement obligations include estimates of the costs of plugging and abandoning oil and gas wells, removing production equipment and facilities, restoring the surface of the land as well as estimates of the economic lives of the oil and gas wells and future inflation rates.

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Income Taxes

9 Months Ended

Sep. 30, 2023

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

The Company provides for income taxes at the statutory rate of 21%. Reported income tax expense differs from the amount of income tax expense that would result from applying domestic federal statutory tax rates to pretax income. These differences primarily relate to non-deductible executive compensation expenses, restricted stock unit windfalls, changes in valuation allowances, and state income taxes.

For the three and nine months ended September 30, 2023, the Company recognized income tax expense of $0.5 million and income tax benefit of $206.4 million, respectively, as a result of the release of the valuation allowance recorded against the Company’s net deferred tax assets as discussed further below. For the three and nine months ended September 30, 2022, the Company recognized

income tax expense of $3.4 million and $6.5 million, respectively, as a result of the full valuation allowance that was in place and the effect of state income taxes.

Deferred Tax Asset Valuation Allowance

Management monitors company-specific, oil and natural gas industry and worldwide economic factors and assesses the likelihood that the Company’s net deferred tax assets will be utilized prior to their expiration. As previously disclosed in the Company’s 2022 Annual Report, beginning in the second quarter of 2020 and through the fourth quarter of 2022, the Company maintained a valuation allowance against its net deferred tax assets. Considering all available evidence (both positive and negative), the Company concluded that it was more likely than not that the deferred tax assets would be realized and released the valuation allowance in the first quarter of 2023. This release resulted in deferred income tax benefit of $0.7 million and $206.1 million for the three and nine months ended September 30, 2023, respectively.

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Share-Based Compensation

9 Months Ended

Sep. 30, 2023

Share-Based Payment Arrangement [Abstract]

Share-Based Compensation

Share-Based Compensation

RSU Equity Awards

The following table summarizes activity for restricted stock units that may be settled in common stock (“RSU Equity Awards”) for the nine months ended September 30, 2023:

	Nine Months Ended September 30, 2023
	RSU Equity Awards (In thousands)	Weighted Average Grant Date Fair Value
Unvested, beginning of the period	800	$44.79
Granted	539	$34.54
Vested	(369)	$39.89
Forfeited	(128)	$44.00
Unvested, end of the period	842	$40.49

Grant activity for the nine months ended September 30, 2023 primarily consisted of RSU Equity Awards granted to executives and employees as part of the annual grant of long-term equity incentive awards with a weighted-average grant date fair value of $34.54.

The aggregate fair value of RSU Equity Awards that vested during the nine months ended September 30, 2023 was $12.3 million. As of September 30, 2023, unrecognized compensation costs related to unvested RSU Equity Awards were $25.3 million and will be recognized over a weighted average period of 2.0 years.

Cash-Settled Awards

As of September 30, 2023 and December 31, 2022, the Company had a total liability of $3.4 million and $6.5 million, respectively, for outstanding Cash-Settled Awards (as defined below). As of December 31, 2022, Cash-Settled Awards consisted of restricted stock unit awards that may be settled in cash (“Cash-Settled RSU Awards”) and stock appreciation rights to be settled in cash (“Cash SARs” and, collectively with the Cash-Settled RSU Awards, the “Cash-Settled Awards”). As of September 30, 2023, there were no Cash-Settled RSU Awards outstanding.

Share-Based Compensation Expense (Benefit), Net

Share-based compensation expense associated with the RSU Equity Awards and the Cash-Settled Awards is included in “General and administrative” in the consolidated statements of operations. The following table presents share-based compensation expense (benefit), net for the periods indicated:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022*	2023	2022*
	(In thousands)
RSU Equity Awards	$3,906	$3,892	$11,613	$11,581
Cash-Settled Awards	49	(2,151)	(2,089)	(7,154)
Total share-based compensation expense (benefit), net	$3,955	$1,741	$9,524	$4,427

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

See “Note 10 — Share-Based Compensation” of the Notes to Consolidated Financial Statements in the 2022 Annual Report for details of the Company’s equity-based incentive plans.

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Stockholders’ Equity

9 Months Ended

Sep. 30, 2023

Equity [Abstract]

Stockholders’ Equity

Stockholders’ Equity

On May 2, 2023, the board of directors (the “Board”) of the Company approved a share repurchase program (the “Share Repurchase Program”), pursuant to which the Company is authorized to repurchase up to $300.0 million of its outstanding common stock through the second quarter of 2025. Repurchases under the Share Repurchase Program may be made, from time to time, in amounts and at prices the Company deems appropriate and will be subject to a variety of factors, including the market price of the Company’s common stock, general market and economic conditions and applicable legal requirements. The Share Repurchase Program may be suspended, modified or discontinued by the Board at any time without prior notice.

During the three months ended September 30, 2023, the Company repurchased and retired 386,719 shares of common stock at a weighted average purchase price of $38.72 per common share for a total cost of approximately $15.0 million. As of September 30, 2023, the remaining authorized repurchase amount under the Share Repurchase Program was $285.0 million.

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Accounts Receivable, Net

9 Months Ended

Sep. 30, 2023

Receivables [Abstract]

Accounts Receivable, Net

Accounts Receivable, Net

	September 30, 2023	December 31, 2022
	(In thousands)
Oil and natural gas receivables	$169,254	$174,107
Joint interest receivables	35,777	16,778
Other receivables	58,531	48,277
Total	263,562	239,162
Allowance for credit losses	(1,168)	(2,034)
Total accounts receivable, net	$262,394	$237,128

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Accounts Payable and Accrued Liabilities

9 Months Ended

Sep. 30, 2023

Payables and Accruals [Abstract]

Accounts Payable and Accrued Liabilities

Accounts Payable and Accrued Liabilities

	September 30, 2023	December 31, 2022
	(In thousands)
Accounts payable	$254,568	$191,133
Revenues and royalties payable	230,918	244,408
Accrued capital expenditures	71,678	58,395
Accrued interest	28,365	42,297
Total accounts payable and accrued liabilities	$585,529	$536,233

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Supplemental Cash Flow

9 Months Ended

Sep. 30, 2023

Supplemental Cash Flow Elements [Abstract]

Supplemental Cash Flow

Supplemental Cash Flow

	Nine Months Ended September 30,
	2023	2022*
	(In thousands)
Supplemental cash flow information:
Interest paid	$142,616	$159,832
Income taxes paid (1)	4,477	—
Non-cash investing and financing activities:
Change in accrued capital expenditures	$41,505	$13,966
Change in asset retirement costs	5,956	3,665

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

(1)    The Company did not pay or receive a refund for any federal income tax for the nine months ended September 30, 2022. For the nine months ended September 30, 2023 and 2022, the Company had net payments of $2.3 million and $0.2 million, respectively, for state income taxes.

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Subsequent Events

9 Months Ended

Sep. 30, 2023

Subsequent Events [Abstract]

Subsequent Events

Subsequent Events

Credit Agreement Reaffirmation

See “Note 8 — Borrowings” for discussion of the results of the Company’s fall 2023 borrowing base redetermination.

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Pay vs Performance Disclosure - USD ($) $ in Thousands	3 Months Ended							9 Months Ended
	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Sep. 30, 2022		Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2023	Sep. 30, 2022
Pay vs Performance Disclosure
Net income (loss)	$ 119,484	$ (107,896)	$ 220,638	$ 502,039	[1]	$ 303,251	$ (7,715)	$ 232,226	$ 797,575	[1],[2]

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

[2] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information

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Insider Trading Arrangements	3 Months Ended
	Sep. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

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Summary of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

Basis of Presentation

Basis of Presentation

The accompanying unaudited interim consolidated financial statements include the accounts of the Company after elimination of intercompany transactions and balances. These financial statements have been prepared pursuant to the rules and regulations of the SEC and therefore do not include all disclosures required for financial statements prepared in conformity with GAAP. In the opinion of management, these financial statements reflect all normal, recurring adjustments and accruals considered necessary to present fairly, in all material respects, the Company’s interim financial position, results of operations and cash flows. However, the results of operations for the periods presented are not necessarily indicative of the results of operations that may be expected for the full year. Certain reclassifications have been made to prior period amounts to conform to the current period presentation. Such reclassifications did not have a material impact on prior period financial statements.

Significant Accounting Policies

The Company’s significant accounting policies are described in “Note 2 — Summary of Significant Accounting Policies” of the Notes to Consolidated Financial Statements in its 2022 Annual Report and are supplemented by the notes included in this Form 10-Q. The financial statements and related notes included in this Form 10-Q should be read in conjunction with the Company’s 2022 Annual Report.

Oil and Natural Gas Properties

Oil and Natural Gas Properties

Proved Oil and Natural Gas Properties. The Company follows the successful efforts method of accounting for its oil and gas properties. Under this method, drilling and completion costs, including lease and well equipment, intangible development costs, and operational support facilities in the field, associated with development wells are capitalized to proved oil and gas properties and are depleted on an asset group basis (properties aggregated based on geographical and geological characteristics) using the units-of-production method based on estimated proved developed oil and gas reserves. The calculation of depletion expense takes into consideration estimated asset retirement costs, net of estimated salvage values.

Proved oil and gas properties are assessed for impairment on an asset group basis whenever events and circumstances indicate that there could be a possible decline in the recoverability of the net book value of such property. The Company estimates the expected

future net cash flows of its proved oil and gas properties and compares these undiscounted cash flows to the net book value of the proved oil and gas properties to determine if the net book value is recoverable. If the net book value exceeds the estimated undiscounted future net cash flows, the Company will recognize an impairment to reduce the net book value of the proved oil and gas properties to fair value. The factors used to determine fair value include, but are not limited to, estimates of reserves, future commodity prices, future production estimates, estimated future development costs and operating costs, and discount rates, which are based on a weighted average cost of capital. See “Note 5 — Acquisitions and Divestitures” for details of the impairment recorded in the second quarter of 2023 associated with the sale of all the Company’s interests of Callon (Eagle Ford) LLC to Ridgemar Energy Operating, LLC.

The partial sale of a proved property within an existing asset group is accounted for as a normal retirement and no net gain or loss on divestiture is recognized as long as the treatment does not significantly alter the units-of-production depletion rate. The sale of a partial interest in an individual proved property is accounted for as a recovery of cost. A net gain or loss on divestiture is recognized in the consolidated statements of operations for all other sales of proved properties.

Unproved Oil and Natural Gas Properties. Unproved oil and gas properties consist of costs incurred in obtaining a mineral interest or a right in a property such as a lease, in addition to broker fees, recording fees and other similar costs. Leasehold costs are classified as unproved until proved reserves are discovered on or otherwise attributed to the property, at which time the related unproved oil and gas property costs are reclassified to proved oil and gas properties and depleted on an asset group basis using the units-of-production method based on estimated total proved oil and gas reserves.

The Company evaluates significant unproved oil and gas property costs for impairment based on remaining lease term, drilling results, reservoir performance, seismic interpretation or changes in future plans to develop acreage. Unproved oil and gas properties that are not individually significant are aggregated by asset group, and the portion of such costs estimated to be nonproductive prior to lease expiration is amortized over the average holding period. The estimate of what could be nonproductive is based on the Company’s historical experience or other information, including current drilling plans and existing geological data. Impairment and amortization of unproved oil and gas properties are recognized as “Impairment of oil and gas properties” in the consolidated statements of operations.

Exploratory. Exploratory costs, including personnel and other internal costs, geological and geophysical expenses and delay rentals for oil and gas leases, are expensed as incurred. Exploratory well costs are initially capitalized pending the determination of whether proved reserves have been discovered. If proved reserves are discovered, exploratory well costs are capitalized as proved oil and gas properties. If proved reserves are not found, exploratory well costs are expensed as dry holes. The application of the successful efforts method of accounting requires management’s judgment to determine the proper designation of wells as either development or exploratory, which will ultimately determine the proper accounting treatment of costs of dry holes.

Capitalized Interest. The Company capitalizes interest on expenditures made in connection with exploration and development projects that meet certain thresholds and are not subject to current amortization. For projects that meet these thresholds, interest is capitalized only for the period that activities are in process to bring the projects to their intended use. Capitalized interest cannot exceed interest expense for the period capitalized. During both the three and nine months ended September 30, 2023 and 2022, the Company did not have any projects that met the thresholds and, therefore, had no capitalized interest.

Share Repurchase Program

Share Repurchase Program

The Company repurchases shares of its common stock from time to time under a program authorized by the Board of Directors. The Company retires shares acquired through share repurchases and returns those shares to the status of authorized but unissued. The repurchased and retired shares are recorded as a reduction to “Common stock” and “Capital in excess of par value” in the consolidated balance sheets. See “Note 13 — Stockholders’ Equity” for further discussion.

Recently Issued Accounting Standards

Recently Issued Accounting Standards

As of September 30, 2023, and through the filing of this report, no new accounting standards have been issued and not yet adopted that are applicable to the Company and that would have a material effect on the Company’s unaudited interim consolidated financial statements and related disclosures.

Subsequent Events

Subsequent Events

The Company evaluates subsequent events through the date the financial statements are issued. See “Note 17 — Subsequent Events” for further discussion.

Revenue from Contracts with Customers

Revenue from Contracts with Customers

The Company recognizes oil, natural gas, and NGL production revenue at the point in time when control of the product transfers to the purchaser, which differs depending on the applicable contractual terms. Transfer of control also drives the presentation of gathering, transportation and processing expenses in the consolidated statements of operations. See “Note 3 — Revenue Recognition” of the Notes to Consolidated Financial Statements in the 2022 Annual Report for more information regarding the types of contracts under which oil, natural gas, and NGL production revenue is generated.

Oil and Gas Purchase and Sale Arrangements

The Company proactively evaluates development plans and looks to enter into pipeline transportation contracts to mitigate market exposures and help ensure certainty of flow for its oil and gas production, in some cases multiple years in advance of development. Additionally, as the Company looks to optimize its operations and reduce exposures, in certain instances, the Company purchases oil and gas from third parties which is utilized to fulfill portions of its pipeline commitments. Sales of purchased oil and gas represent revenues the Company receives from sales of commodities purchased from a third party. The Company recognizes these revenues and the purchase of the third-party commodities, as well as any costs associated with the purchase, on a gross basis, as the Company acts as a principal in these transactions by assuming control of the purchased commodity before it is transferred to the customer.

Accounts Receivable from Revenues from Contracts with Customers

Net accounts receivable include amounts billed and currently due from revenues from contracts with customers of our oil and natural gas production, which had a balance at September 30, 2023 and December 31, 2022 of $169.3 million and $174.1 million, respectively, and are presented in “Accounts receivable, net” in the consolidated balance sheets.

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Change in Accounting Principle (Tables)

9 Months Ended

Sep. 30, 2023

Accounting Changes and Error Corrections [Abstract]

Schedule of Effects of the Change to the Successful Efforts Method

The following tables present the effects of the change to the successful efforts method in the consolidated balance sheets:

	As of September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Oil and natural gas properties:
Proved properties	$11,191,350	($1,947,545)	$9,243,805
Accumulated depreciation, depletion, amortization and impairments	(6,734,174)	2,306,145	(4,428,029)
Unproved properties	1,807,300	(520,281)	1,287,019
Total oil and gas properties, net	6,264,476	(161,681)	6,102,795
Deferred income taxes	170,001	29,733	199,734
Total assets	$6,860,471	($131,948)	$6,728,523
Stockholders’ equity:
Accumulated deficit	(232,855)	(131,948)	(364,803)
Total stockholders' equity	3,993,006	(131,948)	3,861,058
Total liabilities and stockholders' equity	$6,860,471	($131,948)	$6,728,523

	As of December 31, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Oil and natural gas properties:
Proved properties	$10,367,478	($1,099,343)	$9,268,135
Accumulated depreciation, depletion, amortization and impairments	(6,343,875)	1,927,269	(4,416,606)
Unproved properties	1,711,306	(485,538)	1,225,768
Total oil and gas properties, net	5,734,909	342,388	6,077,297
Total assets	$6,146,081	$342,388	$6,488,469
Deferred income taxes (1)	4,279	2,029	6,308
Stockholders’ equity:
Accumulated deficit	(937,388)	340,359	(597,029)
Total stockholders' equity	3,085,422	340,359	3,425,781
Total liabilities and stockholders' equity	$6,146,081	$342,388	$6,488,469

(1)    Included in “Other long-term liabilities” in the consolidated balance sheets.

The following tables present the effects of the change to the successful efforts method in the consolidated statements of operations:

	Three Months Ended September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands, except per share amounts)
Operating Expenses:
Exploration	$—	$3,588	$3,588
Depreciation, depletion and amortization	138,313	285	138,598
Gain on sale of oil and gas properties	—	(20,570)	(20,570)
General and administrative	22,016	7,323	29,339
Income From Operations	211,554	9,374	220,928
Other Expenses:
Interest expense	14,145	29,004	43,149
Income Before Income Taxes	139,623	(19,630)	119,993
Income tax benefit (expense)	10,663	(11,172)	(509)
Net Income	$150,286	($30,802)	$119,484
Net Income Per Common Share:
Basic	$2.21		$1.76
Diluted	$2.21		$1.75

	Three Months Ended September 30, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands, except per share amounts)
Operating Expenses:
Exploration	$—	$2,942	$2,942
Depreciation, depletion and amortization	122,833	7,062	129,895
General and administrative	14,022	10,231	24,253
Income From Operations	440,597	(20,235)	420,362
Other Expenses:
Interest expense	19,468	27,461	46,929
Income Before Income Taxes	553,118	(47,696)	505,422
Income tax expense	(3,515)	132	(3,383)
Net Income	$549,603	($47,564)	$502,039
Net Income Per Common Share:
Basic	$8.91		$8.14
Diluted	$8.88		$8.11

	Nine Months Ended September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands, except per share amounts)
Operating Expenses:
Exploration	$—	$7,702	$7,702
Depreciation, depletion and amortization	396,348	(4,437)	391,911
Impairment of oil and gas properties	—	406,898	406,898
Gain on sale of oil and gas properties	—	(20,570)	(20,570)
General and administrative	56,305	30,600	86,905
Income From Operations	602,555	(420,193)	182,362
Other Expenses:
Interest expense	52,818	83,876	136,694
Income Before Income Taxes	529,897	(504,069)	25,828
Income tax benefit	174,636	31,762	206,398
Net Income	$704,533	($472,307)	$232,226
Net Income Per Common Share:
Basic	$11.04		$3.64
Diluted	$11.01		$3.63

	Nine Months Ended September 30, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands, except per share amounts)
Operating Expenses:
Exploration	$—	$7,237	$7,237
Depreciation, depletion and amortization	335,221	24,273	359,494
General and administrative	42,052	29,433	71,485
Income From Operations	1,356,719	(60,943)	1,295,776
Other Expenses:
Interest expense	61,717	79,303	141,020
Income Before Income Taxes	944,357	(140,246)	804,111
Income tax expense	(7,008)	472	(6,536)
Net Income	$937,349	($139,774)	$797,575
Net Income Per Common Share:
Basic	$15.21		$12.94
Diluted	$15.14		$12.88

The following tables present the effects of the change to the successful efforts method in the consolidated statements of cash flows:

	Nine Months Ended September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Cash flows from operating activities:
Net income	$704,533	($472,307)	$232,226
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	396,348	(4,437)	391,911
Impairment of oil and gas properties	—	406,898	406,898
Amortization of non-cash debt related items, net	3,064	4,915	7,979
Deferred income tax benefit	(174,279)	(31,762)	(206,041)
Gain on sale of oil and gas properties	—	(20,570)	(20,570)
Non-cash expense related to share-based awards	3,848	5,676	9,524
Net cash provided by operating activities	905,850	(111,587)	794,263
Cash flows from investing activities:
Capital expenditures	(854,889)	103,885	(751,004)
Acquisition of oil and gas properties	(286,136)	7,702	(278,434)
Net cash used in investing activities	(592,429)	111,587	(480,842)
Net change in cash and cash equivalents	61	—	61
Balance, beginning of period	3,395	—	3,395
Balance, end of period	$3,456	$—	$3,456

	Nine Months Ended September 30, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Cash flows from operating activities:
Net income	$937,349	($139,774)	$797,575
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	335,221	24,273	359,494
Amortization of non-cash debt related items, net	4,263	5,417	9,680
Deferred income tax expense	1,626	(516)	1,110
Non-cash expense related to share-based awards	1,055	3,372	4,427
Changes in current assets and liabilities:
Accounts payable and accrued liabilities	(8,693)	44	(8,649)
Net cash provided by operating activities	1,128,870	(107,184)	1,021,686
Cash flows from investing activities:
Capital expenditures	(754,225)	106,076	(648,149)
Acquisition of oil and gas properties	(18,114)	1,108	(17,006)
Net cash used in investing activities	(768,700)	107,184	(661,516)
Net change in cash and cash equivalents	(5,532)	—	(5,532)
Balance, beginning of period	9,882	—	9,882
Balance, end of period	$4,350	$—	$4,350

The following tables present the effects of the change to the successful efforts method in the consolidated statements of stockholders’ equity:

	As of September 30, 2023
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Accumulated deficit	($232,855)	($131,948)	($364,803)
Total stockholders’ equity	$3,993,006	($131,948)	$3,861,058

	As of December 31, 2022
	Under Full Cost	Changes	Under Successful Efforts
	(In thousands)
Accumulated deficit	($937,388)	$340,359	($597,029)
Total stockholders’ equity	$3,085,422	$340,359	$3,425,781

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Acquisitions and Divestitures (Tables)

9 Months Ended

Sep. 30, 2023

Business Combination and Asset Acquisition [Abstract]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed

The following table sets forth the Company’s preliminary allocation of the total estimated consideration of $458.5 million to the assets acquired and liabilities assumed as of the acquisition date.

	Preliminary Purchase Price Allocation
	(In thousands)
Assets:
Accounts receivable, net	$30,135
Proved properties, net	491,367
Unproved properties	52,590
Total assets acquired	$574,092
Liabilities:
Accounts payable and accrued liabilities	$42,585
Fair value of derivatives - current	20,660
Other current liabilities	11,471
Asset retirement obligations	2,323
Fair value of derivatives - long-term	27,979
Other long-term liabilities	10,619
Total liabilities assumed	$115,637
Total consideration	$458,455

Schedule of Unaudited Summary Pro Forma Financial Information

The pro forma consolidated statements of operations data has been included for comparative purposes only and is not necessarily indicative of the results that might have occurred had the Percussion Acquisition taken place on January 1, 2022 and is not intended to be a projection of future results.

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022*	2023	2022*
	(In thousands, except per share amounts)
Revenues	$619,298	$928,218	$1,879,442	$2,815,342
Income from operations	220,928	480,459	252,809	1,490,205
Net income	119,484	708,355	360,850	856,610
Basic earnings per common share	$1.76	$10.42	$5.65	$12.62
Diluted earnings per common share	$1.75	$10.40	$5.64	$12.56

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Property and Equipment, Net (Tables)

9 Months Ended

Sep. 30, 2023

Property, Plant and Equipment [Abstract]

Schedule of Property and Equipment, Net

As of September 30, 2023 and December 31, 2022, total property and equipment, net consisted of the following:

	September 30, 2023	December 31, 2022*
Oil and natural gas properties, successful efforts accounting method	(In thousands)
Proved properties	$9,243,805	$9,268,135
Accumulated depreciation, depletion, amortization and impairments	(4,428,029)	(4,416,606)
Proved properties, net	4,815,776	4,851,529
Unproved properties	1,287,019	1,225,768
Total oil and natural gas properties, net	$6,102,795	$6,077,297
Other property and equipment	$40,243	$40,530
Accumulated depreciation	(13,845)	(14,378)
Other property and equipment, net	$26,398	$26,152

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Earnings Per Share (Tables)

9 Months Ended

Sep. 30, 2023

Earnings Per Share [Abstract]

Schedule of Computation of Basic and Diluted Earnings Per Share

The following table sets forth the computation of basic and diluted earnings per share:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022*	2023	2022*
	(In thousands, except per share amounts)
Net Income	$119,484	$502,039	$232,226	$797,575
Basic weighted average common shares outstanding	67,931	61,703	63,827	61,624
Dilutive impact of restricted stock units	152	167	189	303
Diluted weighted average common shares outstanding	68,083	61,870	64,016	61,927
Net Income Per Common Share
Basic	$1.76	$8.14	$3.64	$12.94
Diluted	$1.75	$8.11	$3.63	$12.88
Restricted stock units (1)	54	100	75	28
Warrants (1)	481	481	481	416

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

(1)    Shares excluded from the diluted earnings per share calculation because their effect would be anti-dilutive.

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Borrowings (Tables)

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Schedule of Borrowings

The Company’s borrowings consisted of the following:

	September 30, 2023	December 31, 2022
	(In thousands)
8.25% Senior Notes due 2025	$—	$187,238
6.375% Senior Notes due 2026	320,783	320,783
Senior Secured Revolving Credit Facility due 2027	396,000	503,000
8.0% Senior Notes due 2028	650,000	650,000
7.5% Senior Notes due 2030	600,000	600,000
Total principal outstanding	1,966,783	2,261,021
Unamortized premium on 8.25% Senior Notes	—	1,715
Unamortized deferred financing costs for Senior Notes	(18,164)	(21,441)
Long-term debt (1)	$1,948,619	$2,241,295

(1)    Excludes unamortized deferred financing costs related to the Company’s senior secured revolving credit facility of $14.2 million and $18.8 million as of September 30, 2023 and December 31, 2022, respectively, which are classified in “Deferred financing costs” in the consolidated balance sheets.

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Derivative Instruments and Hedging Activities (Tables)

9 Months Ended

Sep. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Offsetting Assets

The following presents the impact of this presentation to the Company’s recognized assets and liabilities for the periods indicated:

	As of September 30, 2023
	Presented without		As Presented with
	Effects of Netting	Effects of Netting	Effects of Netting
	(In thousands)
Derivative Assets
Commodity derivative instruments	$9,792	($8,596)	$1,196
Fair value of derivatives - current	$9,792	($8,596)	$1,196
Commodity derivative instruments	$4,270	($4,208)	$62
Contingent consideration arrangements	21,680	—	21,680
Fair value of derivatives - non-current	$25,950	($4,208)	$21,742
Derivative Liabilities
Commodity derivative instruments	($57,575)	$8,596	($48,979)
Contingent consideration arrangements	(12,210)	—	(12,210)
Fair value of derivatives - current	($69,785)	$8,596	($61,189)
Commodity derivative instruments	($14,805)	$4,208	($10,597)
Contingent consideration arrangements	(34,210)	—	(34,210)
Fair value of derivatives - non-current	($49,015)	$4,208	($44,807)

	As of December 31, 2022
	Presented without		As Presented with
	Effects of Netting	Effects of Netting	Effects of Netting
	(In thousands)
Derivative Assets
Fair value of derivatives - current	$51,984	($30,652)	$21,332
Fair value of derivatives - non-current	$1,343	($889)	$454
Derivative Liabilities
Fair value of derivatives - current	($46,849)	$30,652	($16,197)
Fair value of derivatives - non-current	($14,304)	$889	($13,415)

Schedule of Offsetting Liabilities

The following presents the impact of this presentation to the Company’s recognized assets and liabilities for the periods indicated:

	As of September 30, 2023
	Presented without		As Presented with
	Effects of Netting	Effects of Netting	Effects of Netting
	(In thousands)
Derivative Assets
Commodity derivative instruments	$9,792	($8,596)	$1,196
Fair value of derivatives - current	$9,792	($8,596)	$1,196
Commodity derivative instruments	$4,270	($4,208)	$62
Contingent consideration arrangements	21,680	—	21,680
Fair value of derivatives - non-current	$25,950	($4,208)	$21,742
Derivative Liabilities
Commodity derivative instruments	($57,575)	$8,596	($48,979)
Contingent consideration arrangements	(12,210)	—	(12,210)
Fair value of derivatives - current	($69,785)	$8,596	($61,189)
Commodity derivative instruments	($14,805)	$4,208	($10,597)
Contingent consideration arrangements	(34,210)	—	(34,210)
Fair value of derivatives - non-current	($49,015)	$4,208	($44,807)

	As of December 31, 2022
	Presented without		As Presented with
	Effects of Netting	Effects of Netting	Effects of Netting
	(In thousands)
Derivative Assets
Fair value of derivatives - current	$51,984	($30,652)	$21,332
Fair value of derivatives - non-current	$1,343	($889)	$454
Derivative Liabilities
Fair value of derivatives - current	($46,849)	$30,652	($16,197)
Fair value of derivatives - non-current	($14,304)	$889	($13,415)

Schedule of Gain or Loss on Derivative Contracts

The components of “(Gain) loss on derivative contracts” are as follows for the respective periods:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022	2023	2022
	(In thousands)
(Gain) loss on oil derivatives	$54,446	($157,731)	$18,165	$243,527
(Gain) loss on natural gas derivatives	(2,315)	22,881	2,380	56,800
Loss on NGL derivatives	2,933	—	2,933	4,771
Loss on contingent consideration arrangements	740	—	740	—
(Gain) loss on derivative contracts	$55,804	($134,850)	$24,218	$305,098

Schedule of Derivative Instruments

The components of “Cash received (paid) for commodity derivative settlements, net” and “Cash received (paid) for settlements of contingent consideration arrangements, net” are as follows for the respective periods:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022	2023	2022
	(In thousands)
Cash flows from operating activities
Cash received (paid) on oil derivatives	$1,680	($117,024)	($4,450)	($374,711)
Cash received (paid) on natural gas derivatives	(560)	(28,572)	17,816	(55,024)
Cash paid on NGL derivatives	(92)	—	(92)	(3,783)
Cash received (paid) for commodity derivative settlements, net	$1,028	($145,596)	$13,274	($433,518)
Cash received for settlements of contingent consideration arrangements, net (1)	$—	$—	$—	$6,492
Cash flows from investing activities
Cash paid for settlement of contingent consideration arrangement (1)	$—	$—	$—	($19,171)
Cash flows from financing activities
Cash received for settlement of contingent consideration arrangement (1)	$—	$—	$—	$8,512

(1)    See “Note 8 — Derivative Instruments and Hedging Activities” of the Notes to Consolidated Financial Statements in our 2022 Annual Report for discussion of the contingent consideration arrangements.

Schedule of Outstanding Oil, Natural Gas, and NGL Derivative Contracts

Listed in the tables below are the outstanding oil, natural gas, and NGL derivative contracts as of September 30, 2023:

	For the Remainder	For the Full Year
Oil Contracts (WTI)	2023	2024
Swap Contracts
Total volume (Bbls)	—	1,076,300
Weighted average price per Bbl	$—	$81.66
Collar Contracts (Three-Way Collars)
Total volume (Bbls)	541,528	3,963,025
Weighted average price per Bbl
Ceiling (short call)	$70.95	$78.86
Floor (long put)	$55.00	$58.16
Floor (short put)	$45.00	$48.16
Collar Contracts (Two-Way Collars)
Total volume (Bbls)	993,455	—
Weighted average price per Bbl
Ceiling (short call)	$87.20	$—
Floor (long put)	$72.04	$—
CMA Roll Swap Contracts
Total volume (Bbls)	838,828	—
Weighted average price per Bbl	$0.30	$—

	For the Remainder	For the Full Year
Natural Gas Contracts (Henry Hub)	2023	2024
Swap Contracts
Total volume (MMBtu)	620,000	—
Weighted average price per MMBtu	$3.00	$—
Collar Contracts
Total volume (MMBtu)	2,201,104	8,598,557
Weighted average price per MMBtu
Ceiling (short call)	$5.37	$3.89
Floor (long put)	$3.14	$3.00
Natural Gas Contracts (Waha Basis Differential)
Swap Contracts
Total volume (MMBtu)	2,460,000	7,320,000
Weighted average price per MMBtu	($1.49)	($1.06)
Natural Gas Contracts (HSC Basis Differential)
Swap Contracts
Total volume (MMBtu)	2,760,000	14,640,000
Weighted average price per MMBtu	($0.29)	($0.42)

	For the Remainder	For the Full Year
NGL Contracts (Mont Belvieu Natural Gasoline)	2023	2024
Swap Contracts
Total volume (Bbls)	43,105	—
Weighted average price per Bbl	$56.38	$—
NGL Contracts (Mont Belvieu Propane)
Swap Contracts
Total volume (Bbls)	35,754	—
Weighted average price per Bbl	$31.27	$—
NGL Contracts (Mont Belvieu Purity Ethane)
Swap Contracts
Total volume (Bbls)	35,095	—
Weighted average price per Bbl	$9.54	$—
NGL Contracts (Mont Belvieu Normal Butane)
Swap Contracts
Total volume (Bbls)	33,470	72,105
Weighted average price per Bbl	$35.56	$33.18
NGL Contracts (Mont Belvieu Isobutane)
Swap Contracts
Total volume (Bbls)	10,967	23,462
Weighted average price per Bbl	$35.42	$33.18

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Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

Summary of Fair Value of Financial Instruments at Carrying and Fair Value

The carrying amount of borrowings outstanding under the Credit Facility approximates fair value as the borrowings bear interest at variable rates and are reflective of market rates. The following table presents the principal amounts of the Senior Notes with the fair values measured using quoted secondary market trading prices which are designated as Level 2 within the valuation hierarchy.

	September 30, 2023		December 31, 2022
	Principal Amount	Fair Value	Principal Amount	Fair Value
	(In thousands)
8.25% Senior Notes	$—	$—	$187,238	$186,719
6.375% Senior Notes	320,783	314,634	320,783	301,732
8.0% Senior Notes	650,000	650,800	650,000	616,935
7.5% Senior Notes	600,000	581,754	600,000	550,812
Total	$1,570,783	$1,547,188	$1,758,021	$1,656,198

Schedule of Fair Value of Assets Measured on Recurring Basis

The following tables present the Company’s assets and liabilities measured at fair value on a recurring basis as of September 30, 2023 and December 31, 2022:

	September 30, 2023
	Level 1	Level 2	Level 3
	(In thousands)
Derivative Assets
Commodity derivative instruments	$—	$1,258	$—
Contingent consideration arrangements	—	21,680	—
Total net assets	$—	$22,938	$—
Derivative Liabilities
Commodity derivative instruments	$—	($59,576)	$—
Contingent consideration arrangements	—	(46,420)	—
Total net liabilities	$—	($105,996)	$—
	December 31, 2022
	Level 1	Level 2	Level 3
	(In thousands)
Commodity derivative assets	$—	$21,786	$—
Commodity derivative liabilities	$—	($29,612)	$—

Schedule of Fair Value of Liabilities Measured on Recurring Basis

The following tables present the Company’s assets and liabilities measured at fair value on a recurring basis as of September 30, 2023 and December 31, 2022:

	September 30, 2023
	Level 1	Level 2	Level 3
	(In thousands)
Derivative Assets
Commodity derivative instruments	$—	$1,258	$—
Contingent consideration arrangements	—	21,680	—
Total net assets	$—	$22,938	$—
Derivative Liabilities
Commodity derivative instruments	$—	($59,576)	$—
Contingent consideration arrangements	—	(46,420)	—
Total net liabilities	$—	($105,996)	$—
	December 31, 2022
	Level 1	Level 2	Level 3
	(In thousands)
Commodity derivative assets	$—	$21,786	$—
Commodity derivative liabilities	$—	($29,612)	$—

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Share-Based Compensation (Tables)

9 Months Ended

Sep. 30, 2023

Share-Based Payment Arrangement [Abstract]

Schedule of RSU Equity Awards

The following table summarizes activity for restricted stock units that may be settled in common stock (“RSU Equity Awards”) for the nine months ended September 30, 2023:

	Nine Months Ended September 30, 2023
	RSU Equity Awards (In thousands)	Weighted Average Grant Date Fair Value
Unvested, beginning of the period	800	$44.79
Granted	539	$34.54
Vested	(369)	$39.89
Forfeited	(128)	$44.00
Unvested, end of the period	842	$40.49

Schedule of Share-based Compensation Expense (Benefit)

The following table presents share-based compensation expense (benefit), net for the periods indicated:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2023	2022*	2023	2022*
	(In thousands)
RSU Equity Awards	$3,906	$3,892	$11,613	$11,581
Cash-Settled Awards	49	(2,151)	(2,089)	(7,154)
Total share-based compensation expense (benefit), net	$3,955	$1,741	$9,524	$4,427

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Accounts Receivable, Net (Tables)

9 Months Ended

Sep. 30, 2023

Receivables [Abstract]

Schedule of Accounts Receivable, Net

	September 30, 2023	December 31, 2022
	(In thousands)
Oil and natural gas receivables	$169,254	$174,107
Joint interest receivables	35,777	16,778
Other receivables	58,531	48,277
Total	263,562	239,162
Allowance for credit losses	(1,168)	(2,034)
Total accounts receivable, net	$262,394	$237,128

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Accounts Payable and Accrued Liabilities (Tables)

9 Months Ended

Sep. 30, 2023

Payables and Accruals [Abstract]

Schedule of Accounts Payable and Accrued Liabilities

	September 30, 2023	December 31, 2022
	(In thousands)
Accounts payable	$254,568	$191,133
Revenues and royalties payable	230,918	244,408
Accrued capital expenditures	71,678	58,395
Accrued interest	28,365	42,297
Total accounts payable and accrued liabilities	$585,529	$536,233

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Supplemental Cash Flow (Tables)

9 Months Ended

Sep. 30, 2023

Supplemental Cash Flow Elements [Abstract]

Schedule of Cash Flow, Supplemental Disclosures

	Nine Months Ended September 30,
	2023	2022*
	(In thousands)
Supplemental cash flow information:
Interest paid	$142,616	$159,832
Income taxes paid (1)	4,477	—
Non-cash investing and financing activities:
Change in accrued capital expenditures	$41,505	$13,966
Change in asset retirement costs	5,956	3,665

*Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

(1)    The Company did not pay or receive a refund for any federal income tax for the nine months ended September 30, 2022. For the nine months ended September 30, 2023 and 2022, the Company had net payments of $2.3 million and $0.2 million, respectively, for state income taxes.

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Change in Accounting Principle - Schedule of Effects of the Change to the Successful Efforts Method in the Consolidated Balance Sheets (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Dec. 31, 2022		Sep. 30, 2022	[2]	Jun. 30, 2022	[2]	Mar. 31, 2022	[2]	Dec. 31, 2021
Oil and natural gas properties:
Proved properties	$ 9,243,805			$ 9,268,135
Accumulated depreciation, depletion, amortization and impairments	(4,428,029)			(4,416,606)
Unproved properties	1,287,019			1,225,768	[1]
Total oil and natural gas properties, net	6,102,795			6,077,297	[1]
Deferred income taxes	199,734			0	[1]
Total assets	6,728,523			6,488,469	[1]
Stockholders’ equity:
Accumulated deficit	(364,803)			(597,029)	[1]
Total stockholders’ equity	3,861,058	$ 3,542,672	$ 3,649,758	3,425,781	[1],[2]	$ 3,199,960		$ 2,697,859		$ 2,397,870		$ 1,865,768
Total liabilities and stockholders’ equity	6,728,523			6,488,469	[1]
Other Noncurrent Liabilities
LIABILITIES AND STOCKHOLDERS’ EQUITY
Deferred income taxes				6,308
Under Full Cost
Oil and natural gas properties:
Proved properties	11,191,350			10,367,478
Accumulated depreciation, depletion, amortization and impairments	(6,734,174)			(6,343,875)
Unproved properties	1,807,300			1,711,306
Total oil and natural gas properties, net	6,264,476			5,734,909
Deferred income taxes	170,001
Total assets	6,860,471			6,146,081
Stockholders’ equity:
Accumulated deficit	(232,855)			(937,388)
Total stockholders’ equity	3,993,006			3,085,422
Total liabilities and stockholders’ equity	6,860,471			6,146,081
Under Full Cost | Other Noncurrent Liabilities
LIABILITIES AND STOCKHOLDERS’ EQUITY
Deferred income taxes				4,279
Changes
Oil and natural gas properties:
Proved properties	(1,947,545)			(1,099,343)
Accumulated depreciation, depletion, amortization and impairments	2,306,145			1,927,269
Unproved properties	(520,281)			(485,538)
Total oil and natural gas properties, net	(161,681)			342,388
Deferred income taxes	29,733
Total assets	(131,948)			342,388
Stockholders’ equity:
Accumulated deficit	(131,948)			340,359
Total stockholders’ equity	(131,948)			340,359
Total liabilities and stockholders’ equity	$ (131,948)			342,388
Changes | Other Noncurrent Liabilities
LIABILITIES AND STOCKHOLDERS’ EQUITY
Deferred income taxes				$ 2,029

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

[2] Financial information for prior periods has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Change in Accounting Principle - Schedule of Effects of the Change to the Successful Efforts Method in the Consolidated Statements of Operations (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended							9 Months Ended
	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Sep. 30, 2022		Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2023	Sep. 30, 2022
Operating Expenses:
Exploration	$ 3,588			$ 2,942	[1]			$ 7,702	$ 7,237	[1]
Depreciation, depletion and amortization	138,598			129,895	[1]			391,911	359,494	[1]
Impairment of oil and gas properties	0			0	[1]			406,898	0	[1],[2]
Gain on sale of oil and gas properties	(20,570)			0	[1]			(20,570)	0	[1]
General and administrative	29,339			24,253	[1]			86,905	71,485	[1]
Income From Operations	220,928			420,362	[1]			182,362	1,295,776	[1]
Other Expenses:
Interest expense	43,149			46,929	[1]			136,694	141,020	[1]
Income Before Income Taxes	119,993			505,422	[1]			25,828	804,111	[1]
Income tax expense (benefit)	(509)			(3,383)	[1]			206,398	(6,536)	[1]
Net Income	$ 119,484	$ (107,896)	$ 220,638	$ 502,039	[1]	$ 303,251	$ (7,715)	$ 232,226	$ 797,575	[1],[2]
Net Income Per Common Share:
Basic (in dollars per share)	$ 1.76			$ 8.14	[1]			$ 3.64	$ 12.94	[1]
Diluted (in dollars per share)	$ 1.75			$ 8.11	[1]			$ 3.63	$ 12.88	[1]
Under Full Cost
Operating Expenses:
Exploration	$ 0			$ 0				$ 0	$ 0
Depreciation, depletion and amortization	138,313			122,833				396,348	335,221
Impairment of oil and gas properties								0
Gain on sale of oil and gas properties	0							0
General and administrative	22,016			14,022				56,305	42,052
Income From Operations	211,554			440,597				602,555	1,356,719
Other Expenses:
Interest expense	14,145			19,468				52,818	61,717
Income Before Income Taxes	139,623			553,118				529,897	944,357
Income tax expense (benefit)	10,663			(3,515)				174,636	(7,008)
Net Income	$ 150,286			$ 549,603				$ 704,533	$ 937,349
Net Income Per Common Share:
Basic (in dollars per share)	$ 2.21			$ 8.91				$ 11.04	$ 15.21
Diluted (in dollars per share)	$ 2.21			$ 8.88				$ 11.01	$ 15.14
Changes
Operating Expenses:
Exploration	$ 3,588			$ 2,942				$ 7,702	$ 7,237
Depreciation, depletion and amortization	285			7,062				(4,437)	24,273
Impairment of oil and gas properties								406,898
Gain on sale of oil and gas properties	(20,570)							(20,570)
General and administrative	7,323			10,231				30,600	29,433
Income From Operations	9,374			(20,235)				(420,193)	(60,943)
Other Expenses:
Interest expense	29,004			27,461				83,876	79,303
Income Before Income Taxes	(19,630)			(47,696)				(504,069)	(140,246)
Income tax expense (benefit)	(11,172)			132				31,762	472
Net Income	$ (30,802)			$ (47,564)				$ (472,307)	$ (139,774)

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

[2] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information

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Change in Accounting Principle - Schedule of Effects of the Change to the Successful Efforts Method in the Consolidated Statements of Cash Flows (Details) - USD ($) $ in Thousands	3 Months Ended								9 Months Ended
	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Sep. 30, 2022		Jun. 30, 2022	Mar. 31, 2022		Sep. 30, 2023	Sep. 30, 2022
Cash flows from operating activities:
Net income (loss)	$ 119,484	$ (107,896)	$ 220,638	$ 502,039	[1]	$ 303,251	$ (7,715)		$ 232,226	$ 797,575	[1],[2]
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization									391,911	359,494	[2]
Impairment of oil and gas properties	0			0	[1]				406,898	0	[1],[2]
Amortization of non-cash debt related items, net									7,979	9,680	[2]
Deferred income tax benefit									(206,041)	1,110	[2]
Gain on sale of oil and gas properties									(20,570)
Non-cash expense related to share-based awards									9,524	4,427	[2]
Accounts payable and accrued liabilities									(69,522)	(8,649)	[2]
Net cash provided by operating activities									794,263	1,021,686	[2]
Cash flows from investing activities:
Capital expenditures									(751,004)	(648,149)	[2]
Acquisition of oil and gas properties									278,434	17,006	[2]
Net cash used in investing activities									(480,842)	(661,516)	[2]
Net change in cash and cash equivalents									61	(5,532)	[2]
Balance, beginning of period			3,395				9,882	[2]	3,395	9,882	[2]
Balance, end of period	3,456			4,350	[2]				3,456	4,350	[2]
Under Full Cost
Cash flows from operating activities:
Net income (loss)	150,286			549,603					704,533	937,349
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization									396,348	335,221
Impairment of oil and gas properties									0
Amortization of non-cash debt related items, net									3,064	4,263
Deferred income tax benefit									(174,279)	1,626
Gain on sale of oil and gas properties									0
Non-cash expense related to share-based awards									3,848	1,055
Accounts payable and accrued liabilities										(8,693)
Net cash provided by operating activities									905,850	1,128,870
Cash flows from investing activities:
Capital expenditures									(854,889)	(754,225)
Acquisition of oil and gas properties									286,136	18,114
Net cash used in investing activities									(592,429)	(768,700)
Net change in cash and cash equivalents									61	(5,532)
Balance, beginning of period			3,395				9,882		3,395	9,882
Balance, end of period	3,456			4,350					3,456	4,350
Changes
Cash flows from operating activities:
Net income (loss)	(30,802)			(47,564)					(472,307)	(139,774)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization									(4,437)	24,273
Impairment of oil and gas properties									406,898
Amortization of non-cash debt related items, net									4,915	5,417
Deferred income tax benefit									(31,762)	(516)
Gain on sale of oil and gas properties									(20,570)
Non-cash expense related to share-based awards									5,676	3,372
Accounts payable and accrued liabilities										44
Net cash provided by operating activities									(111,587)	(107,184)
Cash flows from investing activities:
Capital expenditures									103,885	106,076
Acquisition of oil and gas properties									(7,702)	(1,108)
Net cash used in investing activities									111,587	107,184
Net change in cash and cash equivalents									0	0
Balance, beginning of period			$ 0				$ 0		0	0
Balance, end of period	$ 0			$ 0					$ 0	$ 0

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

[2] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information

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Change in Accounting Principle - Schedule of Effects of the Change to the Successful Efforts Method in the Consolidated Statement of Statements of Stockholders' Equity (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Dec. 31, 2022		Sep. 30, 2022	[2]	Jun. 30, 2022	[2]	Mar. 31, 2022	[2]	Dec. 31, 2021
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Accumulated deficit	$ (364,803)			$ (597,029)	[1]
Total stockholders’ equity	3,861,058	$ 3,542,672	$ 3,649,758	3,425,781	[1],[2]	$ 3,199,960		$ 2,697,859		$ 2,397,870		$ 1,865,768
Under Full Cost
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Accumulated deficit	(232,855)			(937,388)
Total stockholders’ equity	3,993,006			3,085,422
Changes
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Accumulated deficit	(131,948)			340,359
Total stockholders’ equity	(131,948)			340,359
Accumulated deficit
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Accumulated deficit	(364,803)			(597,029)
Total stockholders’ equity	(364,803)	$ (484,287)	$ (376,391)	(597,029)	[2]	$ (818,897)		$ (1,320,936)		$ (1,624,187)		$ (2,147,204)
Accumulated deficit | Under Full Cost
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Accumulated deficit	(232,855)			(937,388)
Accumulated deficit | Changes
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Accumulated deficit	$ (131,948)			$ 340,359

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

[2] Financial information for prior periods has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Revenue Recognition (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Accounts receivable	$ 263,562	$ 239,162
Performance obligation, description of timing	The Company records revenue in the month production is delivered to the purchaser. However, settlement statements for sales may not be received for 30 to 90 days after the date production is delivered, and as a result, the Company is required to estimate the amount of production delivered to the purchaser and the price that will be received for the sale of the product.
Oil and Natural Gas
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Accounts receivable	$ 169,254	$ 174,107

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Acquisitions and Divestitures - Narrative (Details) - USD ($) $ in Thousands, shares in Millions			3 Months Ended					9 Months Ended
	Jul. 03, 2023	May 03, 2023	Sep. 30, 2023	Sep. 30, 2023	Jun. 30, 2023	Sep. 30, 2022	[1]	Sep. 30, 2023	Sep. 30, 2022
Business Acquisition [Line Items]
Impairment of oil and gas properties			$ 0			$ 0		$ 406,898	$ 0	[1],[2]
Proceeds from sales of assets								551,446	9,313	[2]
Gain on sale of oil and gas properties			(20,570)			0		(20,570)	0	[1]
Revenues			619,298			835,877		1,741,627	2,526,715	[1]
Total operating expenses			398,370			$ 415,515		1,559,265	$ 1,230,939	[1]
Percussion Petroleum Operating, LLC
Business Acquisition [Line Items]
Escrow deposit		$ 36,000
Total consideration	$ 458,455	475,000
Amount of cash paid in acquisition	248,500	255,000
Liabilities incurred	$ 220,000	220,000
Consideration transferred, equity issued		210,000
Percentage of interests acquired	100.00%
Shares of common stock issued in acquisition (in shares)	6.3
Contingent consideration arrangements	$ 62,500
Revenues				$ 57,800
Total operating expenses				16,300
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Eagle Ford
Business Acquisition [Line Items]
Purchase price		655,000
Impairment of oil and gas properties					$ 406,900
Proceeds from sales of assets	549,300
Gain on sale of oil and gas properties	$ (20,600)
Contingent consideration arrangements			$ 21,700	$ 21,700				$ 21,700
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Eagle Ford | Ridgemar Energy Operating, LLC
Business Acquisition [Line Items]
Escrow deposit		$ 49,100
Percent of limited liability company interests acquired		100.00%

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

[2] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information

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Acquisitions and Divestitures - Recognized Identified Assets Acquired and Liabilities (Details) - Percussion Petroleum Operating, LLC - USD ($) $ in Thousands	Jul. 03, 2023	May 03, 2023
Business Acquisition [Line Items]
Accounts receivable, net	$ 30,135
Proved properties, net	491,367
Unproved properties	52,590
Total assets acquired	574,092
Accounts payable and accrued liabilities	42,585
Fair value of derivatives - current	20,660
Other current liabilities	11,471
Asset retirement obligations	2,323
Fair value of derivatives - long-term	27,979
Other long-term liabilities	10,619
Total liabilities assumed	115,637
Total consideration	$ 458,455	$ 475,000

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Acquisitions and Divestitures - Unaudited Pro Forma Financial Information (Details) - Percussion Petroleum Operating, LLC - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Business Acquisition [Line Items]
Revenues	$ 619,298	$ 928,218	$ 1,879,442	$ 2,815,342
Income from operations	220,928	480,459	252,809	1,490,205
Net income	$ 119,484	$ 708,355	$ 360,850	$ 856,610
Net income per common share:
Basic earnings per common share (in dollars per share)	$ 1.76	$ 10.42	$ 5.65	$ 12.62
Diluted earnings per common share (in dollars per share)	$ 1.75	$ 10.40	$ 5.64	$ 12.56

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Property and Equipment, Net (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Oil and natural gas properties, successful efforts accounting method
Proved properties	$ 9,243,805	$ 9,268,135
Accumulated depreciation, depletion, amortization and impairments	(4,428,029)	(4,416,606)
Proved properties, net	4,815,776	4,851,529
Unproved properties	1,287,019	1,225,768
Total oil and natural gas properties, net	6,102,795	6,077,297
Other property and equipment	40,243	40,530
Accumulated depreciation	(13,845)	(14,378)
Other property and equipment, net	$ 26,398	$ 26,152	[1]

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended							9 Months Ended
	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Sep. 30, 2022		Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2023	Sep. 30, 2022
Earnings Per Share, Basic and Diluted [Line Items]
Net Income	$ 119,484	$ (107,896)	$ 220,638	$ 502,039	[1]	$ 303,251	$ (7,715)	$ 232,226	$ 797,575	[1],[2]
Basic weighted average common shares outstanding (in shares)	67,931			61,703	[1]			63,827	61,624	[1]
Diluted weighted average common shares outstanding (in shares)	68,083			61,870	[1]			64,016	61,927	[1]
Net Income Per Common Share
Basic (in dollars per share)	$ 1.76			$ 8.14	[1]			$ 3.64	$ 12.94	[1]
Diluted (in dollars per share)	$ 1.75			$ 8.11	[1]			$ 3.63	$ 12.88	[1]
Restricted Stock
Earnings Per Share, Basic and Diluted [Line Items]
Dilutive impact of restricted stock units (in shares)	152			167				189	303
Net Income Per Common Share
Shares excluded from the diluted earnings per share (in shares)	54			100				75	28
Warrants
Net Income Per Common Share
Shares excluded from the diluted earnings per share (in shares)	481			481				481	416

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

[2] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information

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Borrowings - Schedule of Borrowings (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Aug. 02, 2023	Dec. 31, 2022
Principal components:
Total principal outstanding	$ 1,966,783		$ 2,261,021
Long-term debt	1,948,619		2,241,295	[1]
Deferred financing costs	14,235		18,822	[1]
Unsecured debt
Principal components:
Unamortized deferred financing costs for Senior Notes	$ (18,164)		(21,441)
8.25% Senior Notes due 2025
Principal components:
Debt instrument, interest rate, stated (as a percent)	8.25%
8.25% Senior Notes due 2025 | Unsecured debt
Principal components:
Total principal outstanding	$ 0	$ 187,200	187,238
Premium on senior unsecured notes, net of accumulated amortization	$ 0		1,715
Debt instrument, interest rate, stated (as a percent)	8.25%
6.375% Senior Notes due 2026
Principal components:
Debt instrument, interest rate, stated (as a percent)	6.375%
6.375% Senior Notes due 2026 | Unsecured debt
Principal components:
Total principal outstanding	$ 320,783		320,783
Debt instrument, interest rate, stated (as a percent)	6.375%
Senior Secured Revolving Credit Facility due 2027 | Secured Debt
Principal components:
Total principal outstanding	$ 396,000		503,000
8.0% Senior Notes due 2028 | Unsecured debt
Principal components:
Total principal outstanding	$ 650,000		650,000
Debt instrument, interest rate, stated (as a percent)	8.00%
7.5% Senior Notes due 2030
Principal components:
Debt instrument, interest rate, stated (as a percent)	7.50%
7.5% Senior Notes due 2030 | Unsecured debt
Principal components:
Total principal outstanding	$ 600,000		$ 600,000
Debt instrument, interest rate, stated (as a percent)	7.50%

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Borrowings - Senior Secured Revolving Credit Facility (Details) - USD ($)	9 Months Ended
	Sep. 30, 2023	Nov. 01, 2023	Dec. 31, 2022
Line of Credit Facility [Line Items]
Outstanding borrowings	$ 1,966,783,000		$ 2,261,021,000
Senior Secured Revolving Credit Facility due 2027
Line of Credit Facility [Line Items]
Maximum borrowing capacity	5,000,000,000
Credit facility borrowing base	2,000,000,000
Elected commitment amount	$ 1,500,000,000
Interest rate at period end (as a percent)	7.50%
Letters of credit outstanding	$ 21,400,000
Senior Secured Revolving Credit Facility due 2027 | Subsequent Event
Line of Credit Facility [Line Items]
Credit facility borrowing base		$ 2,000,000,000
Senior Secured Revolving Credit Facility due 2027 | Secured Debt
Line of Credit Facility [Line Items]
Outstanding borrowings	$ 396,000,000		$ 503,000,000
Senior Secured Revolving Credit Facility due 2027 | Federal Funds Rate
Line of Credit Facility [Line Items]
Debt instrument, basis spread (as a percent)	0.50%
Senior Secured Revolving Credit Facility due 2027 | SOFR
Line of Credit Facility [Line Items]
Debt instrument, basis spread (as a percent)	0.10%
Senior Secured Revolving Credit Facility due 2027 | Adjusted Base Rate
Line of Credit Facility [Line Items]
Debt instrument, basis spread (as a percent)	1.00%
Senior Secured Revolving Credit Facility due 2027 | Minimum
Line of Credit Facility [Line Items]
Unused capacity, commitment fee (as a percent)	0.375%
Senior Secured Revolving Credit Facility due 2027 | Minimum | Base Rate
Line of Credit Facility [Line Items]
Debt instrument, basis spread (as a percent)	0.75%
Senior Secured Revolving Credit Facility due 2027 | Minimum | SOFR
Line of Credit Facility [Line Items]
Debt instrument, basis spread (as a percent)	1.75%
Senior Secured Revolving Credit Facility due 2027 | Maximum
Line of Credit Facility [Line Items]
Unused capacity, commitment fee (as a percent)	0.50%
Senior Secured Revolving Credit Facility due 2027 | Maximum | Base Rate
Line of Credit Facility [Line Items]
Debt instrument, basis spread (as a percent)	1.75%
Senior Secured Revolving Credit Facility due 2027 | Maximum | SOFR
Line of Credit Facility [Line Items]
Debt instrument, basis spread (as a percent)	2.75%

XML

Borrowings - Redemption of 8.25% Senior Notes Due 2025 (Details) - USD ($) $ in Thousands		3 Months Ended			9 Months Ended
	Aug. 02, 2023	Sep. 30, 2023	Sep. 30, 2022	[1]	Sep. 30, 2023	Sep. 30, 2022	[1]	Dec. 31, 2022
Line of Credit Facility [Line Items]
Outstanding borrowings		$ 1,966,783			$ 1,966,783			$ 2,261,021
Gain on extinguishment of debt		$ (1,238)	$ 0		$ (1,238)	$ 42,417
8.25% Senior Notes due 2025
Line of Credit Facility [Line Items]
Debt instrument, interest rate, stated (as a percent)		8.25%			8.25%
8.25% Senior Notes due 2025 | Unsecured debt
Line of Credit Facility [Line Items]
Debt instrument, interest rate, stated (as a percent)		8.25%			8.25%
Outstanding borrowings	$ 187,200	$ 0			$ 0			$ 187,238
Gain on extinguishment of debt	$ (1,200)

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Borrowings - Covenants (Details)	Sep. 30, 2023
6.375% Senior Notes due 2026
Debt Instrument [Line Items]
Debt instrument, interest rate, stated (as a percent)	6.375%
6.375% Senior Notes due 2026 | Unsecured debt
Debt Instrument [Line Items]
Debt instrument, interest rate, stated (as a percent)	6.375%
8.0% Senior Notes due 2028 | Unsecured debt
Debt Instrument [Line Items]
Debt instrument, interest rate, stated (as a percent)	8.00%
7.5% Senior Notes due 2030
Debt Instrument [Line Items]
Debt instrument, interest rate, stated (as a percent)	7.50%
7.5% Senior Notes due 2030 | Unsecured debt
Debt Instrument [Line Items]
Debt instrument, interest rate, stated (as a percent)	7.50%
Minimum | Senior Secured Revolving Credit Facility due 2027
Debt Instrument [Line Items]
Leverage ratio	100.00%
Maximum | Senior Secured Revolving Credit Facility due 2027
Debt Instrument [Line Items]
Leverage ratio	350.00%

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Derivative Instruments and Hedging Activities - Narrative (Details) $ in Millions	9 Months Ended
	Sep. 30, 2023 USD ($) counterparty $ / barrel	Jul. 03, 2023 USD ($)
Business Acquisition, Contingent Consideration [Line Items]
Number of counterparties | counterparty	9
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Eagle Ford
Business Acquisition, Contingent Consideration [Line Items]
Contingent consideration arrangements	$ 21.7
Derivative liability, fair value, gross liability	10.9
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Eagle Ford | Average Daily Settlement Price Of WTI Crude Oil Greater Than Threshold Price Per Barrel
Business Acquisition, Contingent Consideration [Line Items]
Contingent consideration	45.0
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Eagle Ford | Average Daily Settlement Price Of WTI Crude Oil Less Than Threshold Price Per Barrel
Business Acquisition, Contingent Consideration [Line Items]
Contingent consideration	20.0
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Percussion Earn-Out Obligation
Business Acquisition, Contingent Consideration [Line Items]
Contingent consideration arrangements	46.4
Derivative liability, fair value, gross liability	$ 34.9
Merger, Contingent Percussion Consideration | Remaining Potential Settlements 2023-2025
Business Acquisition, Contingent Consideration [Line Items]
Threshold (in usd per barrel) | $ / barrel	60.00
Merger, Contingent Eagle Ford Consideration | Remaining Potential Settlements 2023-2025
Business Acquisition, Contingent Consideration [Line Items]
Threshold (in usd per barrel) | $ / barrel	80.00
Merger, Contingent Eagle Ford Consideration | Remaining Potential Settlements 2023-2025 | Maximum
Business Acquisition, Contingent Consideration [Line Items]
Threshold (in usd per barrel) | $ / barrel	80.00
Merger, Contingent Eagle Ford Consideration | Remaining Potential Settlements 2023-2025 | Minimum
Business Acquisition, Contingent Consideration [Line Items]
Threshold (in usd per barrel) | $ / barrel	75.00
Percussion Petroleum Operating, LLC
Business Acquisition, Contingent Consideration [Line Items]
Contingent consideration arrangements		$ 62.5

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Derivative Instruments and Hedging Activities - Schedule of Derivative Instruments in Statement of Financial Position, Fair Value (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Offsetting Assets and Liabilities [Line Items]
As Presented with Effects of Netting	$ 1,196	$ 21,332	[1]
As Presented with Effects of Netting	21,742	454	[1]
As Presented with Effects of Netting	(61,189)	(16,197)	[1]
As Presented with Effects of Netting	$ (44,807)	$ (13,415)	[1]
Derivative asset, noncurrent, statement of financial position [extensible enumeration]	Other Assets, Noncurrent	Other Assets, Noncurrent
Derivative liability, current, statement of financial position [extensible enumeration]	As Presented with Effects of Netting	As Presented with Effects of Netting
Derivative liability, noncurrent, statement of financial position [extensible enumeration]	As Presented with Effects of Netting	As Presented with Effects of Netting
Not Designated as Hedging Instrument
Offsetting Assets and Liabilities [Line Items]
As Presented with Effects of Netting	$ 1,196	$ 21,332
As Presented with Effects of Netting	21,742	454
As Presented with Effects of Netting	(61,189)	(16,197)
As Presented with Effects of Netting	(44,807)	(13,415)
Not Designated as Hedging Instrument | Commodity Derivative Instruments
Offsetting Assets and Liabilities [Line Items]
As Presented with Effects of Netting	1,196
As Presented with Effects of Netting	62
As Presented with Effects of Netting	(48,979)
As Presented with Effects of Netting	(10,597)
Not Designated as Hedging Instrument | Contingent consideration arrangements
Offsetting Assets and Liabilities [Line Items]
As Presented with Effects of Netting	21,680
As Presented with Effects of Netting	(12,210)
As Presented with Effects of Netting	(34,210)
Not Designated as Hedging Instrument | Derivative Assets, Current
Offsetting Assets and Liabilities [Line Items]
Presented without Effects of Netting	9,792	51,984
Effects of Netting	(8,596)	(30,652)
Not Designated as Hedging Instrument | Derivative Assets, Current | Commodity Derivative Instruments
Offsetting Assets and Liabilities [Line Items]
Presented without Effects of Netting	9,792
Effects of Netting	(8,596)
Not Designated as Hedging Instrument | Derivative Assets, Noncurrent
Offsetting Assets and Liabilities [Line Items]
Presented without Effects of Netting	25,950	1,343
Effects of Netting	(4,208)	(889)
Not Designated as Hedging Instrument | Derivative Assets, Noncurrent | Commodity Derivative Instruments
Offsetting Assets and Liabilities [Line Items]
Presented without Effects of Netting	4,270
Effects of Netting	(4,208)
Not Designated as Hedging Instrument | Derivative Assets, Noncurrent | Contingent consideration arrangements
Offsetting Assets and Liabilities [Line Items]
Presented without Effects of Netting	21,680
Effects of Netting	0
Not Designated as Hedging Instrument | Derivative Liabilities, Current
Offsetting Assets and Liabilities [Line Items]
Presented without Effects of Netting	(69,785)	(46,849)
Effects of Netting	8,596	30,652
Not Designated as Hedging Instrument | Derivative Liabilities, Current | Commodity Derivative Instruments
Offsetting Assets and Liabilities [Line Items]
Presented without Effects of Netting	(57,575)
Effects of Netting	8,596
Not Designated as Hedging Instrument | Derivative Liabilities, Current | Contingent consideration arrangements
Offsetting Assets and Liabilities [Line Items]
Presented without Effects of Netting	(12,210)
Effects of Netting	0
Not Designated as Hedging Instrument | Derivative Liabilities, Noncurrent
Offsetting Assets and Liabilities [Line Items]
Presented without Effects of Netting	(49,015)	(14,304)
Effects of Netting	4,208	$ 889
Not Designated as Hedging Instrument | Derivative Liabilities, Noncurrent | Commodity Derivative Instruments
Offsetting Assets and Liabilities [Line Items]
Presented without Effects of Netting	(14,805)
Effects of Netting	4,208
Not Designated as Hedging Instrument | Derivative Liabilities, Noncurrent | Contingent consideration arrangements
Offsetting Assets and Liabilities [Line Items]
Presented without Effects of Netting	(34,210)
Effects of Netting	$ 0

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Derivative Instruments and Hedging Activities - Schedule of Gain or Loss on Derivative Contracts (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022		Sep. 30, 2023	Sep. 30, 2022
Derivative Instruments, Gain (Loss) [Line Items]
(Gain) loss on derivative contracts	$ (55,804)	$ 134,850	[1]	$ (24,218)	$ (305,098)	[1]
Not Designated as Hedging Instrument
Derivative Instruments, Gain (Loss) [Line Items]
(Gain) loss on derivative contracts	55,804	(134,850)		24,218	305,098
Not Designated as Hedging Instrument | Loss on contingent consideration arrangements
Derivative Instruments, Gain (Loss) [Line Items]
(Gain) loss on derivative contracts	740	0		740	0
Not Designated as Hedging Instrument | (Gain) loss on oil derivatives
Derivative Instruments, Gain (Loss) [Line Items]
(Gain) loss on derivative contracts	54,446	(157,731)		18,165	243,527
Not Designated as Hedging Instrument | (Gain) loss on natural gas derivatives
Derivative Instruments, Gain (Loss) [Line Items]
(Gain) loss on derivative contracts	(2,315)	22,881		2,380	56,800
Not Designated as Hedging Instrument | Loss on NGL derivatives
Derivative Instruments, Gain (Loss) [Line Items]
(Gain) loss on derivative contracts	$ 2,933	$ 0		$ 2,933	$ 4,771

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Derivative Instruments and Hedging Activities - Schedule of Cash Paid (Received) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Cash flows from operating activities
Cash paid for commodity derivative settlements, net	$ 1,028	$ (145,596)	$ 13,274	$ (433,518)	[1]
Not Designated as Hedging Instrument | Loss on contingent consideration arrangements
Cash flows from operating activities
Cash received for settlements of contingent consideration arrangements, net	0	0	0	6,492
Cash flows from investing activities
Cash paid for settlement of contingent consideration arrangement	0	0	0	(19,171)
Cash flows from financing activities
Cash received for settlement of contingent consideration arrangement	0	0	0	8,512
Commodity - Oil | Not Designated as Hedging Instrument
Cash flows from operating activities
Cash paid for commodity derivative settlements, net	1,680	(117,024)	(4,450)	(374,711)
Natural gas | Not Designated as Hedging Instrument
Cash flows from operating activities
Cash paid for commodity derivative settlements, net	(560)	(28,572)	17,816	(55,024)
Natural gas liquids | Not Designated as Hedging Instrument
Cash flows from operating activities
Cash paid for commodity derivative settlements, net	$ (92)	$ 0	$ (92)	$ (3,783)

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information

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Derivative Instruments and Hedging Activities - Schedule of Outstanding Oil, Natural Gas, and NGL Derivative Contracts (Details) - Forecast - Not Designated as Hedging Instrument	3 Months Ended	12 Months Ended
	Dec. 31, 2023 MMBTU $ / barrel $ / MMBTU bbl	Dec. 31, 2024 MMBTU $ / MMBTU $ / barrel bbl
(Gain) loss on oil derivatives
Derivative [Line Items]
Total volume (Bbls) | bbl	0	1,076,300
Weighted average price (in dollars per share) | $ / barrel	0	81.66
(Gain) loss on oil derivatives | Short | Percussion Acquisition | CMA Roll Swap Contracts [Member]
Derivative [Line Items]
Total volume (Bbls) | bbl		0
(Gain) loss on oil derivatives | Short | Percussion Acquisition | CMA Roll Swap Contracts [Member] | Call option
Derivative [Line Items]
Total volume (Bbls) | bbl	838,828
Weighted average price (in dollars per share)	0.30
(Gain) loss on oil derivatives | Call option | Short | Percussion Acquisition | CMA Roll Swap Contracts [Member]
Derivative [Line Items]
Weighted average price (in dollars per share)		0
(Gain) loss on oil derivatives | Collar Contracts (Three-Way Collars)
Derivative [Line Items]
Total volume (Bbls) | bbl	541,528	3,963,025
(Gain) loss on oil derivatives | Collar Contracts (Three-Way Collars) | Call option | Short
Derivative [Line Items]
Weighted average price (in dollars per share) | $ / barrel	70.95	78.86
(Gain) loss on oil derivatives | Collar Contracts (Three-Way Collars) | Put option | Short
Derivative [Line Items]
Weighted average price (in dollars per share) | $ / barrel	45.00	48.16
(Gain) loss on oil derivatives | Collar Contracts (Three-Way Collars) | Put option | Long
Derivative [Line Items]
Weighted average price (in dollars per share) | $ / barrel	55.00	58.16
(Gain) loss on oil derivatives | Collar Contracts (Two-Way Collars)
Derivative [Line Items]
Total volume (Bbls) | bbl	993,455	0
(Gain) loss on oil derivatives | Collar Contracts (Two-Way Collars) | Call option | Short
Derivative [Line Items]
Weighted average price (in dollars per share) | $ / barrel	87.20	0
(Gain) loss on oil derivatives | Collar Contracts (Two-Way Collars) | Put option | Long
Derivative [Line Items]
Weighted average price (in dollars per share) | $ / barrel	72.04	0
Natural gas
Derivative [Line Items]
Total volume (MMBtu) | MMBTU	620,000	0
Weighted average price (in dollars per share)	3.00	0
Natural gas | Collar Contracts
Derivative [Line Items]
Total volume (MMBtu) | MMBTU	2,201,104	8,598,557
Natural gas | Collar Contracts | Call option | Short
Derivative [Line Items]
Weighted average price (in dollars per share)	5.37	3.89
Natural gas | Collar Contracts | Put option | Long
Derivative [Line Items]
Weighted average price (in dollars per share)	3.14	3.00
Natural gas | Natural Gas Contracts (Waha Basis Differential)
Derivative [Line Items]
Total volume (MMBtu) | MMBTU	2,460,000	7,320,000
Weighted average price (in dollars per share)	1.49	1.06
Natural gas | Natural Gas Contracts (HSC Basis Differential)
Derivative [Line Items]
Total volume (MMBtu) | MMBTU	2,760,000	14,640,000
Weighted average price (in dollars per share)	0.29	0.42
Natural gas liquids | NGL Contracts (Mont Belvieu Natural Gasoline) [Member] | Percussion Acquisition | Swap Contracts
Derivative [Line Items]
Total volume (Bbls) | bbl	43,105	0
Weighted average price (in dollars per share)	56.38	0
Natural gas liquids | NGL Contracts (Mont Belvieu Propane) [Member] | Percussion Acquisition | Swap Contracts
Derivative [Line Items]
Total volume (Bbls) | bbl	35,754	0
Weighted average price (in dollars per share)	31.27	0
Natural gas liquids | NGL Contracts (Mont Belvieu Purity Ethane) [Member] | Percussion Acquisition | Swap Contracts
Derivative [Line Items]
Total volume (Bbls) | bbl	35,095	0
Weighted average price (in dollars per share)	9.54	0
Natural gas liquids | NGL Contracts (Mont Belvieu Normal Butane) [Member] | Percussion Acquisition | Swap Contracts
Derivative [Line Items]
Total volume (Bbls) | bbl	33,470	72,105
Weighted average price (in dollars per share)	35.56	33.18
Natural gas liquids | NGL Contracts (Mont Belvieu Isobutane) [Member] | Percussion Acquisition | Swap Contracts
Derivative [Line Items]
Total volume (Bbls) | bbl	10,967	23,462
Weighted average price (in dollars per share)	35.42	33.18

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Fair Value Measurements - Summary of Financial Instruments at Carrying and Fair Value (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
8.25% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument, interest rate, stated (as a percent)	8.25%
6.375% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument, interest rate, stated (as a percent)	6.375%
8.0% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument, interest rate, stated (as a percent)	8.00%
7.5% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument, interest rate, stated (as a percent)	7.50%
Unsecured debt | 8.25% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument, interest rate, stated (as a percent)	8.25%
Unsecured debt | 6.375% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument, interest rate, stated (as a percent)	6.375%
Unsecured debt | 7.5% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument, interest rate, stated (as a percent)	7.50%
Principal Amount | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total	$ 1,570,783	$ 1,758,021
Principal Amount | Level 2 | Unsecured debt | 8.25% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior notes	0	187,238
Principal Amount | Level 2 | Unsecured debt | 6.375% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior notes	320,783	320,783
Principal Amount | Level 2 | Unsecured debt | 8.0% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior notes	650,000	650,000
Principal Amount | Level 2 | Unsecured debt | 7.5% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior notes	600,000	600,000
Fair Value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total	1,547,188	1,656,198
Fair Value | Level 2 | Unsecured debt | 8.25% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior notes	0	186,719
Fair Value | Level 2 | Unsecured debt | 6.375% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior notes	314,634	301,732
Fair Value | Level 2 | Unsecured debt | 8.0% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior notes	650,800	616,935
Fair Value | Level 2 | Unsecured debt | 7.5% Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior notes	$ 581,754	$ 550,812

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Fair Value Measurements - Fair Value of Assets and Liabilities Measured on Recurring Basis (Details) - Recurring Basis - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Level 1
Derivative Assets
Total net assets	$ 0
Derivative Liabilities
Total net liabilities	0
Level 1 | Commodity derivative instruments
Derivative Assets
Total net assets	0	$ 0
Derivative Liabilities
Total net liabilities	0	0
Level 1 | Contingent consideration arrangements
Derivative Assets
Total net assets	0
Derivative Liabilities
Total net liabilities	0
Level 2
Derivative Assets
Total net assets	22,938
Derivative Liabilities
Total net liabilities	(105,996)
Level 2 | Commodity derivative instruments
Derivative Assets
Total net assets	1,258	21,786
Derivative Liabilities
Total net liabilities	(59,576)	(29,612)
Level 2 | Contingent consideration arrangements
Derivative Assets
Total net assets	21,680
Derivative Liabilities
Total net liabilities	(46,420)
Level 3
Derivative Assets
Total net assets	0
Derivative Liabilities
Total net liabilities	0
Level 3 | Commodity derivative instruments
Derivative Assets
Total net assets	0	0
Derivative Liabilities
Total net liabilities	0	$ 0
Level 3 | Contingent consideration arrangements
Derivative Assets
Total net assets	0
Derivative Liabilities
Total net liabilities	$ 0

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Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	[1]	Sep. 30, 2023	Sep. 30, 2022	[1]
Income Tax Disclosure [Abstract]
Income taxes at statutory tax rate, percent				21.00%
Income tax expense (benefit)	$ (509)	$ (3,383)		$ 206,398	$ (6,536)
Deferred income tax expense (benefit)	$ 700			$ 206,100

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Share-Based Compensation - Schedule of RSU Equity Awards (Details) - RSU Equity Awards shares in Thousands	9 Months Ended
	Sep. 30, 2023 $ / shares shares
RSU Equity Awards
Unvested, beginning of the period (in shares) | shares	800
Granted (in shares) | shares	539
Vested (in shares) | shares	(369)
Forfeited (in shares) | shares	(128)
Unvested, end of the period (in shares) | shares	842
Weighted Average Grant Date Fair Value
Unvested, beginning of the period (in dollars per share) | $ / shares	$ 44.79
Granted (in dollars per share) | $ / shares	34.54
Vested (in dollars per share) | $ / shares	39.89
Forfeited (in dollars per share) | $ / shares	44.00
Unvested, end of the period (in dollars per share) | $ / shares	$ 40.49

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Share-Based Compensation - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based payment arrangement, cash used to settle award	$ 3.4	$ 6.5
RSU Equity Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in dollars per share)	$ 34.54
Grant date fair value	$ 12.3
Unrecognized compensation costs	$ 25.3
Period for recognition (in years)	2 years

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Share-Based Compensation - Schedule of Share-based Compensation Expense (Benefit) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ 3,955	$ 1,741	$ 9,524	$ 4,427
RSU Equity Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	3,906	3,892	11,613	11,581
Cash-Settled Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ 49	$ (2,151)	$ (2,089)	$ (7,154)

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Stockholders’ Equity (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2023	Sep. 30, 2022	[1]	May 02, 2023
Equity, Class of Treasury Stock [Line Items]
Stock repurchase program, authorized amount					$ 300,000
Cash paid to repurchase common stock		$ 14,980	$ 0
Share Repurchase Program
Equity, Class of Treasury Stock [Line Items]
Stock repurchased (in shares)	386,719
Shares acquired, average cost per share (in dollars per share)	$ 38.72
Cash paid to repurchase common stock	$ 15,000
Stock repurchase program, remaining	$ 285,000	$ 285,000

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information

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Accounts Receivable, Net (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total	$ 263,562	$ 239,162
Allowance for credit losses	(1,168)	(2,034)
Total accounts receivable, net	262,394	237,128	[1]
Joint interest receivables
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total	35,777	16,778
Other receivables
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total	58,531	48,277
Oil and natural gas receivables
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total	$ 169,254	$ 174,107

[1] Financial information for the prior period has been recast to reflect retrospective application of the successful efforts method of accounting. See “Note 2 - Summary of Significant Accounting Policies” for additional information.

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Accounts Payable and Accrued Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Payables and Accruals [Abstract]
Accounts payable	$ 254,568	$ 191,133
Revenues and royalties payable	230,918	244,408
Accrued capital expenditures	71,678	58,395
Accrued interest	28,365	42,297
Total accounts payable and accrued liabilities	$ 585,529	$ 536,233

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Supplemental Cash Flow (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Supplemental cash flow information:
Interest paid	$ 142,616	$ 159,832
Income taxes paid	4,477	0
Non-cash investing and financing activities:
Change in accrued capital expenditures	41,505	13,966
Change in asset retirement costs	5,956	3,665
Income taxes paid, net	$ 2,300	$ 200