Kosmos Energy (KOS) 10-K 24 Feb 25 2024 FY Annual report Financial data

Cover

Cover - USD ($)	12 Months Ended
	Dec. 31, 2024	Feb. 20, 2025	Jun. 30, 2024
Cover [Abstract]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2024
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	001-35167
Entity Registrant Name	Kosmos Energy Ltd.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	98-0686001
Entity Address, Address Line One	8176 Park Lane
Entity Address, City or Town	Dallas,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	75231
City Area Code	214
Local Phone Number	445 9600
Title of 12(b) Security	Common Stock $0.01 par value
Trading Symbol	KOS
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
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
ICFR Auditor Attestation Flag	true
Document Financial Statement Error Correction [Flag]	false
Entity Shell Company	false
Entity Public Float			$ 2,558,615,971
Entity Common Stock, Shares Outstanding		477,904,652
Documents Incorporated by Reference	Part III, Items 10‑14, is incorporated by reference from the Proxy Statement for the Annual Meeting of Shareholders which will be filed with the Securities and Exchange Commission not later than 120 days subsequent to December 31, 2024. Certain exhibits previously filed with the Securities and Exchange Commission are incorporated by reference into Part IV of this report.
Entity Central Index Key	0001509991
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	FY

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2024
Audit Information [Abstract]
Auditor Firm ID	42
Auditor Name	Ernst & Young LLP
Auditor Location	Dallas, Texas

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2024	Dec. 31, 2023
Current assets:
Cash and cash equivalents	$ 84,972	$ 95,345
Receivables	164,959	120,733
Inventories	170,871	152,054
Prepaid expenses and other	16,414	46,235
Derivatives	8,916	8,346
Total current assets	446,132	422,713
Property and equipment, net	4,444,221	4,160,229
Other assets:
Restricted cash	305	3,416
Long-term receivables	385,463	325,181
Deferred tax assets	4,717	3,033
Derivatives	512	1,594
Other	27,638	21,968
Total assets	5,308,988	4,938,134
Current liabilities:
Accounts payable	349,994	248,912
Accrued liabilities	244,954	302,815
Derivatives	0	3,103
Total current liabilities	594,948	554,830
Long-term liabilities:
Long-term debt, net	2,744,712	2,390,914
Asset retirement obligations	406,886	343,979
Deferred tax liabilities	313,433	363,918
Other long-term liabilities	48,585	252,156
Total long-term liabilities	3,513,616	3,350,967
Stockholders’ equity:
Preference shares, $0.01 par value; 200,000,000 authorized shares; zero issued at December 31, 2024 and December 31, 2023	0	0
Common stock, $0.01 par value; 2,000,000,000 authorized shares; 516,158,749 and 504,392,980 issued at December 31, 2024 and December 31, 2023, respectively	5,162	5,044
Additional paid-in capital	2,514,739	2,536,621
Accumulated deficit	(1,082,470)	(1,272,321)
Treasury stock, at cost, 44,263,269 shares at December 31, 2024 and December 31, 2023, respectively	(237,007)	(237,007)
Total stockholders’ equity	1,200,424	1,032,337
Total liabilities and stockholders’ equity	$ 5,308,988	$ 4,938,134

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2024	Dec. 31, 2023
Statement of Financial Position [Abstract]
Preference shares, par value (in dollars per share)	$ 0.01	$ 0.01
Preference shares, authorized shares (in shares)	200,000,000	200,000,000
Preference shares, issued shares (in shares)	0	0
Common shares, par value (in dollars per share)	$ 0.01	$ 0.01
Common shares, authorized shares (in shares)	2,000,000,000	2,000,000,000
Common shares, issued shares (in shares)	516,158,749	504,392,980
Treasury stock shares (in shares)	44,263,269	44,263,269

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Revenues and other income:
Oil and gas revenue	$ 1,675,358,000	$ 1,701,608,000	$ 2,245,355,000
Gain on sale of assets	0	0	50,471,000
Other income, net	204,000	(73,000)	3,949,000
Total revenues and other income	1,675,562,000	1,701,535,000	2,299,775,000
Costs and expenses:
Oil and gas production	530,514,000	390,097,000	409,299,000
Exploration expenses	119,907,000	42,278,000	134,230,000
General and administrative	100,155,000	99,532,000	100,856,000
Depletion, depreciation and amortization	456,774,000	444,927,000	498,256,000
Impairment of long-lived assets	0	222,278,000	449,969,000
Interest and other financing costs, net	88,598,000	95,904,000	118,260,000
Derivatives, net	12,099,000	11,128,000	260,892,000
Other expenses, net	17,703,000	23,656,000	(9,054,000)
Total costs and expenses	1,325,750,000	1,329,800,000	1,962,708,000
Income before income taxes	349,812,000	371,735,000	337,067,000
Income tax expense	159,961,000	158,215,000	110,516,000
Net income (loss)	$ 189,851,000	$ 213,520,000	$ 226,551,000
Net income per share:
Basic (in dollars per share)	$ 0.40	$ 0.46	$ 0.50
Diluted (in dollars per share)	$ 0.40	$ 0.44	$ 0.48
Weighted average number of shares used to compute net income per share:
Basic (in shares)	470,844	459,641	455,346
Diluted (in shares)	476,691	481,070	474,857

CONSOLIDATED STATEMENTS OF SHAR

CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY - USD ($) shares in Thousands, $ in Thousands	Total	Common Stock	Additional Paid-in Capital	Accumulated Deficit	Treasury Stock
Balance at the beginning (in shares) at Dec. 31, 2021		496,152
Balance at the beginning at Dec. 31, 2021	$ 529,237	$ 4,962	$ 2,473,674	$ (1,712,392)	$ (237,007)
Increase (Decrease) in Shareholders' Equity
Dividends	(39)		(39)
Equity-based compensation	34,852		34,852
Restricted stock units (in shares)		4,009
Restricted stock units	0	$ 40	(40)
Tax withholdings and cash settlements on restricted stock units	(2,753)		(2,753)
Net income	226,551			226,551
Balance at the end (in shares) at Dec. 31, 2022		500,161
Balance at the end at Dec. 31, 2022	787,848	$ 5,002	2,505,694	(1,485,841)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends	(1)		(1)
Equity-based compensation	42,780		42,780
Restricted stock units (in shares)		4,232
Restricted stock units	0	$ 42	(42)
Tax withholdings and cash settlements on restricted stock units	(11,810)		(11,810)
Net income	213,520			213,520
Balance at the end (in shares) at Dec. 31, 2023		504,393
Balance at the end at Dec. 31, 2023	1,032,337	$ 5,044	2,536,621	(1,272,321)	(237,007)
Increase (Decrease) in Shareholders' Equity
Capped call transactions	(49,800)		(49,800)
Equity-based compensation	37,957		37,957
Restricted stock units (in shares)		11,766
Restricted stock units	0	$ 118	(118)
Tax withholdings and cash settlements on restricted stock units	(9,921)		(9,921)
Net income	189,851			189,851
Balance at the end (in shares) at Dec. 31, 2024		516,159
Balance at the end at Dec. 31, 2024	$ 1,200,424	$ 5,162	$ 2,514,739	$ (1,082,470)	$ (237,007)

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Operating activities
Net income	$ 189,851,000	$ 213,520,000	$ 226,551,000
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion, depreciation and amortization (including deferred financing costs)	465,483,000	454,848,000	508,657,000
Deferred income taxes	(52,174,000)	(107,560,000)	(197,487,000)
Unsuccessful well costs and leasehold impairments	74,489,000	2,208,000	86,941,000
Impairment of long-lived assets	0	222,278,000	449,969,000
Change in fair value of derivatives	14,747,000	28,349,000	275,465,000
Cash settlements on derivatives, net (including $(12.5) million and $(16.4) million and $(327.9) million on commodity hedges during 2024, 2023, and 2022)	(19,652,000)	(32,426,000)	(344,468,000)
Equity-based compensation	37,951,000	42,693,000	34,546,000
Gain on sale of assets	0	0	(50,471,000)
Debt modifications and extinguishments	25,173,000	1,503,000	192,000
Other	(13,735,000)	5,709,000	(10,099,000)
Changes in assets and liabilities:
(Increase) decrease in receivables	(63,331,000)	(16,223,000)	68,829,000
(Increase) decrease in inventories and prepaid expenses	4,988,000	(45,667,000)	(704,000)
Increase (decrease) in accounts payable and accrued liabilities	14,459,000	(4,062,000)	82,555,000
Net cash provided by operating activities	678,249,000	765,170,000	1,130,476,000
Investing activities
Oil and gas assets	(933,659,000)	(932,603,000)	(787,297,000)
Acquisition of oil and gas properties	0	0	(22,078,000)
Proceeds on sale of assets	0	0	168,703,000
Notes receivable and other investing activities	(32,397,000)	(62,247,000)	(63,183,000)
Net cash used in investing activities	(966,056,000)	(994,850,000)	(703,855,000)
Financing activities
Borrowings under long-term debt	325,000,000	300,000,000	0
Payments on long-term debt	(350,000,000)	(145,000,000)	(405,000,000)
Net proceeds from issuance of senior notes	885,285,000	0	0
Repurchase of senior notes	(499,515,000)	0	0
Purchase of capped call transactions	(49,800,000)	0	0
Dividends	0	(166,000)	(655,000)
Other financing costs	(36,647,000)	(13,214,000)	(9,041,000)
Net cash provided by (used in) financing activities	274,323,000	141,620,000	(414,696,000)
Net increase (decrease) in cash, cash equivalents and restricted cash	(13,484,000)	(88,060,000)	11,925,000
Cash, cash equivalents and restricted cash at beginning of period	98,761,000	186,821,000	174,896,000
Cash, cash equivalents and restricted cash at end of period	85,277,000	98,761,000	186,821,000
Cash paid for:
Income taxes, net of refund received	$ 281,005,000	$ 281,872,000	$ 247,889,000

CONSOLIDATED STATEMENTS OF CA_2

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Statement of Cash Flows [Abstract]
Cash settlements on commodity hedges derivatives	$ (12.5)	$ (16.4)	$ (327.9)

Organization

Organization	12 Months Ended
	Dec. 31, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization	Organization Kosmos Energy Ltd. changed our jurisdiction of incorporation from Bermuda to the State of Delaware in December 2018 as a holding company for Kosmos Energy Delaware Holdings, LLC, a Delaware limited liability company. As a holding company, Kosmos Energy Ltd.’s management operations are conducted through a wholly-owned subsidiary, Kosmos Energy, LLC. The terms “Kosmos,” the “Company,” “we,” “us,” “our,” “ours,” and similar terms refer to Kosmos Energy Ltd. and its wholly-owned subsidiaries, unless the context indicates otherwise. Kosmos Energy is a leading deepwater exploration and production company focused on meeting the world’s growing demand for energy. We have diversified oil and gas production from assets offshore Ghana, Equatorial Guinea, Mauritania, Senegal and the Gulf of America (formerly the U.S. Gulf of Mexico). Additionally, in the proven basins where we operate we are advancing high-quality development opportunities, which have come from our exploration success. Kosmos is listed on the NYSE and LSE and is traded under the ticker symbol KOS. Kosmos is engaged in a single line of business, which is the exploration, development, and production of oil and natural gas. Substantially all of our long-lived assets and all of our product sales are related to operations in four geographic areas: Ghana, Equatorial Guinea, Mauritania/Senegal and the Gulf of America.

Accounting Policies

Accounting Policies	12 Months Ended
	Dec. 31, 2024
Accounting Policies [Abstract]
Accounting Policies	Accounting Policies Principles of Consolidation The accompanying consolidated financial statements include the accounts of Kosmos Energy Ltd. and its wholly-owned subsidiaries. They also include the Company’s share of the undivided interest in certain assets, liabilities, revenues and expenses. Use of Estimates The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosures of contingent assets and liabilities. These estimates could change materially if different information or assumptions were used. We base our assumptions and estimates on historical experience and other sources that we believe to be reasonable at the time. Actual results could differ from these estimates. Reclassifications Certain prior period amounts have been reclassified to conform with the current year presentation. Such reclassifications had no significant impact on our reported net income, current assets, total assets, current liabilities, total liabilities, shareholders’ equity or cash flows. Cash, Cash Equivalents and Restricted Cash December 31, 2024 2023 2022 (In thousands) Cash and cash equivalents $ 84,972 $ 95,345 $ 183,405 Restricted cash - long-term 305 3,416 3,416 Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 85,277 $ 98,761 $ 186,821 Cash and cash equivalents includes demand deposits and funds invested in highly liquid instruments with original maturities of three months or less at the date of purchase. When our net leverage ratio exceeds 2.50x, we are required under the Facility to maintain a restricted cash balance that is sufficient to meet the payment of interest and fees for the next six-month period on the 7.125% Senior Notes, the 7.750% Senior Notes, the 7.500% Senior Notes, the 8.750% Senior Notes and the 3.125% Convertible Senior Notes or the Facility, whichever is greater. As of December 31, 2024, our net leverage ratio was 2.54x, partially due to pre-production operating costs associated with the GTA Phase 1 project. Our next financial covenant assessment date is March 31, 2025, after which date we could be required to restrict approximately $66.0 million in cash as required under the terms of the Facility unless otherwise waived by the lenders. As of December 31, 2023 our net leverage ratio was below 2.50x. Receivables Our receivables consist of joint interest billings, oil and gas sales, related party and other receivables. Receivables from joint interest owners are stated at amounts due, net of any allowances for doubtful accounts. As required by ASU 2016-13, "Measurement of Credit Losses on Financial Instruments", we determine our allowance based on historical experience, current conditions and reasonable and supportable forecasts by considering the length of time past due, future net revenues of the debtor’s ownership interest in oil and natural gas properties we operate, and the owner’s ability to pay its obligation, among other things. We had an allowance for doubtful accounts of $13.6 million and $9.8 million in current joint interest billings receivables as of December 31, 2024 and 2023, respectively. Inventories Inventories consisted of $167.5 million and $143.0 million of materials and supplies and $3.4 million and $9.1 million of hydrocarbons as of December 31, 2024 and 2023, respectively. The Company’s materials and supplies inventory primarily consists of casing and wellheads and is stated at the lower of cost, using the weighted average cost method, or net realizable value. We recorded write downs of $1.8 million, $7.4 million and $1.5 million during the years ended December 31, 2024, 2023 and 2022 for materials and supplies inventories as Other expenses, net in the consolidated statements of operations and other in the consolidated statements of cash flows. Hydrocarbon inventory is carried at the lower of cost, using the weighted average cost method, or net realizable value. Hydrocarbon inventory costs include expenditures and other charges incurred in bringing the inventory to its existing condition. Selling expenses and general and administrative expenses are reported as period costs and excluded from inventory costs. Exploration and Development Costs The Company follows the successful efforts method of accounting for its oil and gas properties. Acquisition costs for proved and unproved properties are capitalized when incurred. Costs of unproved properties are transferred to proved properties when a determination that proved reserves have been found. Exploration costs, including geological and geophysical costs and costs of carrying unproved properties, are expensed as incurred. Exploratory drilling costs are capitalized when incurred. If exploratory wells are determined to be commercially unsuccessful or dry holes, the applicable costs are expensed and recorded in exploration expense on the consolidated statement of operations. Costs incurred to drill and equip development wells, including unsuccessful development wells, are capitalized. Costs incurred to operate and maintain wells and equipment and to lift oil and natural gas to the surface are expensed as oil and gas production expense. The Company evaluates unproved property periodically for impairment. The impairment assessment considers results of exploration activities, commodity price outlooks, planned future sales or expiration of all or a portion of such projects. If it is determined that future appraisal drilling or development activities are unlikely to occur, the associated capitalized costs are recorded as exploration expense in the consolidated statement of operations. Depletion, Depreciation and Amortization Proved properties and support equipment and facilities are depleted using the unit‑of‑production method based on estimated proved oil and gas reserves. Capitalized exploratory drilling costs that result in a discovery of proved reserves and development costs are depleted using the unit‑of‑production method based on estimated proved developed oil and gas reserves for the related field. Depreciation and amortization of other property is computed using the straight-line method over the assets’ estimated useful lives (not to exceed the lease term for leasehold improvements), ranging from one Years Leasehold improvements 1 to 8 Office furniture, fixtures and computer equipment 3 to 7 Amortization of deferred financing costs is computed using the straight‑line method over the life of the related debt. Capitalized Interest Interest costs from external borrowings are capitalized on major projects with an expected construction period of one year or longer. Capitalized interest is added to the cost of the underlying asset and is depleted on the unit‑of‑production method in the same manner as the underlying assets. Asset Retirement Obligations The Company accounts for asset retirement obligations as required by ASC 410—Asset Retirement and Environmental Obligations. Under these standards, the fair value of a liability for an asset retirement obligation is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. If a reasonable estimate of fair value cannot be made in the period the asset retirement obligation is incurred, the liability is recognized when a reasonable estimate of fair value can be made. If a tangible long‑lived asset with an existing asset retirement obligation is acquired, a liability for that obligation is recognized at the asset’s acquisition or in service date. In addition, a liability for the fair value of a conditional asset retirement obligation is recorded if the fair value of the liability can be reasonably estimated. We capitalize the asset retirement costs by increasing the carrying amount of the related long‑lived asset by the same amount as the liability. We record increases in the discounted abandonment liability resulting from the passage of time in depletion, depreciation and amortization in the consolidated statement of operations. Estimating the future restoration and removal costs requires management to make estimates and judgments because most of the removal obligations are many years in the future and the regulations in some countries that we operate often have vague descriptions of what constitutes removal. Additionally, asset removal technologies and costs are constantly changing, as are regulatory, political, environmental, safety and public relations considerations. Inherent in the present value calculation are numerous assumptions and judgments including the ultimate settlement amounts, inflation factors, credit adjusted discount rates, timing of settlement and changes in the legal, regulatory, environmental and political environments. To the extent future revisions to these assumptions impact the present value of the existing asset retirement obligations, a corresponding adjustment is made to the oil and gas property balance. Acquisition Accounting The purchase price in an acquisition (business combination or asset acquisition) is allocated to the assets acquired and liabilities assumed based on their relative fair values as of the acquisition date, which may occur many months after the deal announcement date. Therefore, while the consideration to be paid may be fixed, the fair value of the assets acquired, and liabilities assumed is subject to change during the period between the announcement date and the acquisition date. The most significant estimates in the allocation typically relate to the value assigned to future recoverable oil and gas reserves and unproved properties. As the allocation of the purchase price is subject to significant estimates and subjective judgments, the accuracy of this assessment is inherently uncertain. Impairment of Long‑lived Assets We review our long‑lived assets for impairment when changes in circumstances indicate that the carrying amount of an asset may not be recoverable. ASC 360 — Property, Plant and Equipment requires an impairment loss to be recognized if the carrying amount of a long‑lived asset is not recoverable and exceeds its fair value. The carrying amount of a long‑lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. That assessment shall be based on the carrying amount of the asset at the date it is tested for recoverability, whether in use or under development. Assets to be disposed of and assets not expected to provide any future service potential to us are recorded at the lower of carrying amount or fair value. Oil and gas properties are grouped in accordance with ASC 932 — Extractive Activities-Oil and Gas. The basis for grouping is a reasonable aggregation of properties typically by field or by logical grouping of assets with significant shared infrastructure. For long-lived assets whereby the carrying value exceeds the estimated future undiscounted cash flows, the carrying amount is reduced to fair value. Fair value is generally estimated using the income approach described in the ASC 820 — Fair Value Measurement. If applicable, we utilize prices and other relevant information generated by market transactions involving assets and liabilities that are identical or comparable to the item being measured as the basis for determining fair value. The expected future cash flows used for impairment reviews and related fair value measurements are typically based on judgmental assessments of future production, pricing estimates, capital and operating costs, market-based weighted average cost of capital, and risk adjustment factors applied to reserves. These assumptions are applied to develop future cash flow projections that are then discounted to estimated fair value, using a market-based weighted-average cost of capital. We believe the assumptions used in our analysis to test for impairment are appropriate and result in a reasonable estimate of future cash flows and fair value. Kosmos has consistently used an average of third-party industry forecasts to determine our pricing assumptions. Where unproved reserves exist, an appropriately risk-adjusted amount of these reserves may be included in the evaluation. Derivative Instruments and Hedging Activities We utilize oil derivative contracts to mitigate our exposure to commodity price risk associated with our anticipated future oil production. These derivative contracts consist of collars, put options, call options and swaps. We also have used interest rate derivative contracts to mitigate our exposure to interest rate fluctuations related to our long‑term debt. Our derivative financial instruments are recorded on the balance sheet as either assets or liabilities and are measured at fair value. We do not apply hedge accounting to our derivative contracts. See Note 9—Derivative Financial Instruments. Estimates of Proved Oil and Gas Reserves Reserve quantities and the related estimates of future net cash flows affect our periodic calculations of depletion and assessment of impairment of our oil and natural gas properties. Proved oil and gas reserves are the estimated quantities of crude oil, natural gas and natural gas liquids that geological and engineering data demonstrate with reasonable certainty to be recoverable in future periods from known reservoirs under existing economic and operating conditions. Proved reserve quantities and future cash flows are estimated by independent petroleum engineering consultants and prepared in accordance with guidelines established by the SEC and the FASB. The accuracy of these reserve estimates is a function of: • the engineering and geological interpretation of available data; • estimates of the amount and timing of future operating cost, production taxes, development cost and workover cost; • the accuracy of various mandated economic assumptions; and • the judgments of the persons preparing the estimates. Revenue Recognition We recognize revenues on the volumes of hydrocarbons sold to a purchaser. The volumes sold may be more or less than the volumes to which we are entitled based on our ownership interest in the property. These differences result in a condition known in the industry as a production imbalance. A receivable or liability is recognized only to the extent that we have an imbalance on a specific property greater than the expected remaining proved reserves on such property. As of December 31, 2024 and 2023, we had no oil and gas imbalances recorded in our consolidated financial statements. Our oil and gas revenues are recognized when hydrocarbons have been sold to a purchaser at a fixed or determinable price, title has transferred and collection is probable. Certain revenues are based on contracts with provisional pricing and quantity optionality which contain a derivative that is separated from the host contract for accounting purposes. The host contract is the receivable from oil sales at the spot price on the date of sale. The derivative, which is not designated as a hedge, is marked to market through oil and gas revenue each period until the final settlement occurs, which generally is limited to the month of or month after the sale. Oil and gas revenue is composed of the following: Years Ended December 31, 2024 2023 2022 (In thousands) Revenues from contracts with customers: Equatorial Guinea $ 257,961 $ 273,280 $ 349,443 Ghana 1,052,126 1,073,917 1,362,875 Gulf of America 370,121 371,632 547,610 Total revenues from contracts with customers 1,680,208 1,718,829 2,259,928 Provisional oil sales contracts (4,850) (17,221) (14,573) Oil and gas revenue $ 1,675,358 $ 1,701,608 $ 2,245,355 Equity‑based Compensation For equity‑based compensation awards, compensation expense is recognized in the Company’s financial statements over the awards’ vesting periods based on their grant date fair value. The Company utilizes (i) the closing stock price on the date of grant to determine the fair value of service vesting restricted stock units and (ii) a Monte Carlo simulation to determine the fair value of restricted stock units with a combination of market and service vesting criteria. Forfeitures are recognized in the period in which they occur. Income Taxes The Company accounts for income taxes as required by ASC 740—Income Taxes. Under this method, deferred income taxes are determined based on the difference between the financial statement and tax basis of assets and liabilities using enacted tax rates in effect for the year in which the differences are expected to reverse. Valuation allowances are established when necessary to reduce deferred tax assets to the amounts expected to be realized. On a quarterly basis, management evaluates the need for and adequacy of valuation allowances based on the expected realizability of the deferred tax assets and adjusts the amount of such allowances, if necessary. We recognize tax benefits from uncertain tax positions only if it is more likely than not that the tax position will be sustained upon examination by the tax authorities, based on the technical merits of the position. Accordingly, we measure tax benefits from such positions based on the most likely outcome to be realized. Foreign Currency Translation The U.S. dollar is the functional currency for all of the Company’s material foreign operations. Foreign currency transaction gains and losses and adjustments resulting from translating monetary assets and liabilities denominated in foreign currencies are included in other expenses. Cash balances held in foreign currencies are not significant, and as such, the effect of exchange rate changes is not material to any reporting period. Concentration of Credit Risk Our revenue can be materially affected by current economic conditions and the price of oil and natural gas. However, based on the current demand for crude oil and natural gas and the fact that alternative purchasers are readily available, we believe that the loss of our marketing agents and/or any of the purchasers identified by our marketing agents would not have a long‑term material adverse effect on our financial position or results of international operations. The economic disruption resulting from Russia’s continued war in Ukraine, ongoing instability in the Middle East, a potential global recession, inflationary pressures and other varying macroeconomic conditions could materially impact the Company's business in future periods. Any potential disruption will depend on the duration and intensity of these events, which are highly uncertain and cannot be predicted at this time. Recent Accounting Standards Recently Adopted In November 2023, the FASB issued “ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The amendment requires disclosures of significant segment expenses that are regularly provided to the chief operating decision maker (“CODM”) and included within each reported measure of segment profit or loss, an amount and description of its composition for other segment items, and interim disclosures of a reportable segment’s profit of loss and assets. The amendments are effective for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Not Yet Adopted

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2024
Business Combination, Asset Acquisition, and Joint Venture Formation [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures 2024 Transactions In March 2024, Kosmos completed the acquisition of an additional 16.7% participating interest in the Tiberius area in Keathley Canyon Blocks 920 and 964 offshore Gulf of America. As a result of the transaction, Kosmos’ participating interest in Tiberius increased from 33.3% to 50.0%. In December 2024, we submitted a formal notice to the Ministry of Hydrocarbons and Mining Development that we are electing to exit Block 21 offshore Equatorial Guinea. 2023 Transactions In February 2023, Kosmos entered into a petroleum contract covering Block EG-01 offshore Equatorial Guinea with the Republic of Equatorial Guinea. Kosmos holds a 24% non-operated participating interest in the block. Block EG-01 currently comprises approximately 59,400 acres (240 square kilometers), with a first exploration period of three years from the effective date (March 1, 2023). In November 2023, BP decided not to participate in the future development and exploitation of the Yakaar and Teranga discoveries. In accordance with the provisions of the Contract for Exploration and Production Sharing of Hydrocarbons for the Cayar Offshore Profond Block (the “Contract”) and the related Joint Operating Agreement (the “JOA”), BP has waived its rights in respect of the Yakaar and Teranga discoveries. As provided in the JOA, Kosmos has assumed BP’s participating interest under the Contract and the JOA and has become operator of the Cayar Offshore Profond Block, with customary government approvals having been received effective January 18, 2024. The participating interests in the Cayar Offshore Profond Block are: Kosmos 90% and PETROSEN 10%, with PETROSEN having the right to increase its participating interest after issuance of an exploitation authorization to up to 35%. 2022 Transactions In March 2022, Kosmos completed the acquisition of an additional 5.5% interest in Winterfell area in Green Canyon Blocks 943, 944, 987 and 988, offshore Gulf of America, and an additional 1.5% interest in Green Canyon blocks 899 and 900 for $9.6 million. Additionally, in September 2022, Kosmos completed the acquisition of an additional 3.2% interest in the Winterfell area in Green Canyon Blocks 943, 944, 987 and 988 and an additional 1.4% interest in Green Canyon Blocks 899 and 900 for $6.6 million. As a result of the two transactions, our participating interests in the Green Canyon Blocks 943, 944, 987 and 988 is now 25.0% and our participating interests in the Green Canyon Blocks 899 and 900 is 37.8%. In May 2022, Kosmos and its joint venture partners agreed with the Ministry of Hydrocarbons and Mining Development of Equatorial Guinea to extend the Block G petroleum contract term harmonizing the expiration of the Ceiba Field and Okume Complex production licenses (from 2029 and 2034 respectively) to 2040. In June 2022, Kosmos completed the acquisition of an additional 5.9% interest in the Kodiak oil field from Marubeni by exercising our preferential right to purchase for a total purchase price of approximately $29.0 million. The purchase price was based on an initial purchase price of $38.3 million reduced by certain purchase adjustments totaling approximately $9.3 million. The purchase price allocation was based on the estimated fair value of identifiable assets acquired and liabilities assumed primarily comprised of $27.1 million of oil and gas properties, net. As a result of the transaction, our working interest increased from 29.1% to 35.0%. In June 2022, at the conclusion of the second exploration period, Block C12 offshore Mauritania was relinquished. In October 2022, we entered into a farm-out agreement with Panoro Energy ASA (Panoro) to farm-out a 6.0% participating interest in Block S offshore Equatorial Guinea, which reduced our participating interest in Block S to 34.0%, in exchange for cash consideration totaling approximately $1.8 million. In March 2023, the transaction was approved by the Government of Equatorial Guinea and the farm-out agreement was closed. In October 2021, Kosmos completed the acquisition of Anadarko WCTP Company (“Anadarko WCTP”), a subsidiary of Occidental Petroleum Corporation, which owns a participating interest in the WCTP Block and DT Block offshore Ghana, including an 18.0% participating interest in the Jubilee Unit Area and an 11.1% participating interest in the TEN Fields. Following closing of the acquisition, Kosmos’ interest in the Jubilee Unit Area increased from 24.1% to 42.1%, and Kosmos’ interest in the TEN Fields increased from 17.0% to 28.1%. Under the DT Block Joint Operating Agreement, certain joint venture partners have pre-emption rights in the Jubilee Unit Area and the TEN Fields. In November 2021, we received notice from Tullow Oil plc (“Tullow”) that they were exercising their pre-emption rights in relation to Kosmos’ acquisition of Anadarko WCTP. After execution of definitive transaction documentation and receipt of government approvals, Kosmos concluded the pre-emption transaction with Tullow in March 2022. Following the completion of the pre-emption process, Kosmos’ interest in the Jubilee Unit Area decreased from 42.1% to 38.6% and Kosmos’ interest in the TEN Fields decreased from 28.1% to 20.4%. Tullow paid Kosmos $118.2 million in cash consideration after post closing adjustments for the pre-emption. During the first quarter of 2022, our oil and gas properties, net balance was reduced by $175.5 million, which includes the cash proceeds and net liabilities transferred to the purchaser as a result of concluding the Tullow pre-emption transaction. The difference in the net book value of the proved property, net liabilities transferred and adjusted purchase price qualified for treatment as a recovery of cost and normal retirement under ASC 932, which resulted in no gain or loss being recognized.

Receivables

Receivables	12 Months Ended
	Dec. 31, 2024
Receivables [Abstract]
Receivables	Receivables Receivables consisted of the following: December 31, 2024 2023 (In thousands) Joint interest billings, net 33,120 35,632 Oil sales 89,694 64,958 Other current receivables 42,145 20,143 Total receivables 164,959 120,733 Long-term receivables 385,463 325,181 The Company’s joint interest billings consist of receivables from partners with interests in common oil and gas properties operated by the Company for shared costs. Joint interest billings are classified as current and long-term receivables based on when collection is expected to occur. Long-term receivables In February 2019, Kosmos and BP signed Carry Advance Agreements with the national oil companies of Mauritania and Senegal obligating us to finance a portion of the respective national oil companies’ share of certain development costs incurred for the GTA Phase 1 project. The amount financed by Kosmos is to be repaid with interest through the national oil companies’ share of future revenues. As of December 31, 2024 and 2023, the principal balance due from the national oil companies was $280.1 million and $259.2 million, respectively, which is classified as Long-term receivables in our consolidated balance sheets. As of December 31, 2024 and 2023, accrued interest on the balance due from the national oil companies was $56.6 million and $37.3 million, respectively, which is classified as Long-term receivables in our consolidated balance sheets. Interest income on the long-term notes receivable was $19.3 million, $15.9 million and $10.1 million for the years ended December 31, 2024, 2023 and 2022, respectively. In August 2021, BP, as the operator of the Greater Tortue project (“BP Operator”), with the consent of the Greater Tortue Unit participants and the respective States, agreed to sell the Greater Tortue FPSO to an affiliate of BP Operator (“BP Buyer”) once the construction has been completed by Technip Energies and the Greater Tortue FPSO has been commissioned (the “FPSO Handover”). As a result of the above transactions entered into by BP Operator, Kosmos recognized a Long-term receivable of $200.2 million from BP Operator for our share of the consideration paid from BP Buyer to and held by BP Operator as well as a $200.2 million FPSO Contract Liability in Other long-term liabilities related to the deferred sale of the Greater Tortue FPSO. As of December 31, 2022, this Long-term receivable was non-cash settled against obligations payable to BP Operator, which included $132.4 million and $67.8 million of non-cash capital expenditures during the fourth quarter of 2021 and the first quarter of 2022, respectively. Delivery of the Greater Tortue FPSO to BP Buyer and FPSO Handover occurred during the fourth quarter of 2024. The $200.2 million FPSO Contract Liability in Other long-term liabilities related to the deferred sale of the Greater Tortue FPSO was non-cash settled against FPSO asset costs in our consolidated balance sheet as of December 31, 2024, reducing both assets and liabilities. These non-cash impacts are excluded from the statement of cash flows.

Property and Equipment

Property and Equipment	12 Months Ended
	Dec. 31, 2024
Property, Plant and Equipment [Abstract]
Property and Equipment	Property and Equipment Property and equipment is stated at cost and consisted of the following: December 31, 2024 2023 (In thousands) Oil and gas properties: Proved properties $ 8,342,353 $ 7,600,252 Unproved properties 386,292 423,050 Total oil and gas properties 8,728,645 8,023,302 Accumulated depletion (4,288,215) (3,868,946) Oil and gas properties, net 4,440,430 4,154,356 Other property 66,675 65,095 Accumulated depreciation (62,884) (59,222) Other property, net 3,791 5,873 Property and equipment, net $ 4,444,221 $ 4,160,229 We recorded depletion expense of $419.3 million, $411.6 million and $471.4 million and depreciation expense of $3.7 million, $3.7 million and $3.6 million for the years ended December 31, 2024, 2023 and 2022, respectively. In connection with fair value assessments for oil and gas proved properties, we recorded asset impairments of 222.3 million and $450.0 million related to the TEN Fields in Ghana during the years ended December 31, 2023 and 2022, respectively in our consolidated statement of operations. No proved property impairments were recorded for the year ended December 31, 2024. During the year ended December 31, 2024 we wrote off $37.6 million of capitalized exploratory costs associated with the S-5 exploration well. During the year ended December 31, 2024, additions to our proved properties primarily related to continued infill development drilling campaign in the Jubilee Field in Ghana, the Ceiba and Okume infill development drilling campaign in Equatorial Guinea, development costs associated with Phase 1 of the Greater Tortue Ahmeyim project in Mauritania and Senegal, the first phase of the Winterfell development project and the Odd Job Field subsea pump installation in the Gulf of America, offset by the non-cash settlement of the $200.2 million FPSO Contract Liability related to the deferred sale of the Greater Tortue FPSO against FPSO asset costs. During the year ended December 31, 2023, additions to our unproved properties primarily related to the Winterfell development project and the drilling of the Tiberius infrastructure-led exploration prospect. Additions to our proved properties for the year ended December 31, 2023 primarily related to continued infill development in the Jubilee Field in Ghana including the successful startup of the Jubilee Southeast project with the installation of a new subsea production manifold, the Odd Job Field subsea pump installation in the Gulf of America and continued progress on the development of the Greater Tortue Ahmeyim project in Mauritania/Senegal.

Suspended Well Costs

Suspended Well Costs	12 Months Ended
	Dec. 31, 2024
Oil and Gas Disclosure [Abstract]
Suspended Well Costs	Suspended Well Costs The Company capitalizes exploratory well costs as unproved properties within oil and gas properties until a determination is made that the well has either found proved reserves or is impaired. If proved reserves are found, the capitalized exploratory well costs are reclassified to proved properties. Well costs are charged to exploration expense if the exploratory well is determined to be impaired. The following table reflects the Company’s capitalized exploratory well costs on drilled wells as of and during the years ended December 31, 2024, 2023 and 2022. Years Ended December 31, 2024 2023 2022 (In thousands) Beginning balance $ 211,959 $ 145,957 $ 218,180 Additions to capitalized exploratory well costs pending the determination of proved reserves 21,418 66,002 25,209 Reclassification due to determination of proved reserves(1) — — (34,614) Capitalized exploratory well costs charged to expense(2) (37,175) — (62,818) Ending balance $ 196,202 $ 211,959 $ 145,957 ______________________________________ (1) Activity for the year ended December 31, 2022 represents the reclassification of exploratory well costs associated with the Winterfell discovery in Green Canyon Block 944 in the Gulf of America. (2) Activity for the year ended December 31, 2024 represents the impairment of exploratory well costs associated with the Asam discovery in Block S offshore Equatorial Guinea. Activity for the year ended December 31, 2022 represents the impairment of exploratory well costs associated with the BirAllah and Orca discoveries as a result of the expiration of the exploration period of Block C8 in June 2022. The following table provides aging of capitalized exploratory well costs based on the date drilling was completed and the number of projects for which exploratory well costs have been capitalized for more than one year since the completion of drilling: Years Ended December 31, 2024 2023 2022 (In thousands, except well counts) Exploratory well costs capitalized for a period of one year or less $ — $ 54,274 $ — Exploratory well costs capitalized for a period of one to five years 63,552 34,775 75,941 Exploratory well costs capitalized for a period of six to ten years 132,650 122,910 70,016 Ending balance $ 196,202 $ 211,959 $ 145,957 Number of projects that have exploratory well costs that have been capitalized for a period greater than one year 2 2 2 As of December 31, 2024, the projects with exploratory well costs capitalized for more than one year since the completion of drilling are related to the Yakaar and Teranga discoveries in the Cayar Offshore Profond block offshore Senegal and the Tiberius discovery located in Keathley Canyon Block 964 in the Outer Wilcox play in the Gulf of America. Yakaar and Teranga Discoveries — In May 2016, we drilled the Teranga-1 exploration well in the Cayar Offshore Profond Block offshore Senegal, which encountered hydrocarbon pay. In June 2017, we drilled the Yakaar-1 exploration well in the Cayar Offshore Profond Block offshore Senegal, which encountered hydrocarbon pay. In November 2017, an integrated Yakaar-Teranga appraisal plan was submitted to the Government of Senegal. In September 2019, we drilled the Yakaar-2 appraisal well which encountered hydrocarbon pay. The Yakaar-2 well was drilled approximately nine kilometers from the Yakaar-1 exploration well. In March 2024, the current phase of the Cayar Block exploration license was extended an additional two years to July 2026. The Yakaar and Teranga discoveries continue to be progressed as a joint development. During 2024, we continued progressing appraisal studies and maturing concept design. Following additional evaluation, a final investment decision for the development of the project is expected to be made. Tiberius Discovery — In July 2023, we spud the Tiberius infrastructure-led exploration prospect located in Block 964 of Keathley Canyon in the Gulf of America, which encountered hydrocarbon pay. Initial fluid and core analysis supports the production potential of the well, which characteristics analogous with similar nearby discoveries in the Wilcox trend. In March 2024, we completed the acquisition of an additional 16.7% participating interest in the Keathley Canyon Blocks 920 and 964, offshore Gulf of America. As a result of the transaction, Kosmos’ participating interest in the Tiberius discovery area increased from 33.3% to 50.0%. The Tiberius project is being analyzed as a phased development with discussions currently ongoing with our partner to finalize the development plan. Following additional evaluation, a final investment decision for the development of the project is expected to be made.

Leases

Leases	12 Months Ended
	Dec. 31, 2024
Leases [Abstract]
Leases	Leases We have commitments under operating leases primarily related to office leases. Our leases have initial lease terms ranging from one year to ten years. Certain lease agreements contain provisions for future rent increases. The components of lease cost for the years ended December 31, 2024, 2023 and 2022 is as follows: December 31, 2024 2023 2022 (In thousands) Operating lease cost $ 3,864 $ 3,866 $ 3,882 Variable lease cost 1,963 1,766 1,825 Short-term lease cost(1) 12,281 17,464 13,970 Total lease cost $ 18,108 $ 23,096 $ 19,677 __________________________________ (1) Includes $10.7 million, $16.0 million and $12.4 million during the years ended December 31, 2024, 2023 and 2022, respectively, of costs associated with short-term drilling contracts. Other information related to operating leases at December 31, 2024 and 2023, is as follows: December 31, 2024 2023 (In thousands, except lease term and discount rate) Balance sheet classifications Other assets (right-of-use assets) $ 12,294 $ 14,234 Accrued liabilities (current maturities of leases) 2,816 2,492 Other long-term liabilities (non-current maturities of leases) 12,745 15,576 Weighted average remaining lease term 4.6 years 5.6 years Weighted average discount rate 9.8 % 9.8 % The table below presents supplemental cash flow information related to leases during the years ended December 31, 2024, 2023 and 2022: December 31, 2024 2023 2022 (In thousands) Operating cash flows for operating leases $ 7,683 $ 7,256 $ 7,170 Investing cash flows for operating leases(1) 10,746 16,029 12,449 __________________________________ (1) Represents costs associated with short-term drilling contracts. Future minimum rental commitments under our leases at December 31, 2024, are as follows: Operating Leases(1) (In thousands) 2025 $ 4,189 2026 4,260 2027 4,201 2028 3,844 2029 2,808 Thereafter — Total undiscounted lease payments $ 19,302 Less: Imputed interest (3,741) Total lease liabilities $ 15,561 __________________________________ (1) Does not include purchase commitments for jointly owned fields and facilities where we are not the operator and excludes commitments for exploration activities, including well commitments, in our petroleum contracts.

Debt

Debt	12 Months Ended
	Dec. 31, 2024
Debt Disclosure [Abstract]
Debt	Debt December 31, 2024 2023 (In thousands) Outstanding debt principal balances: Facility $ 900,000 $ 925,000 7.125% Senior Notes 250,000 650,000 7.750% Senior Notes 350,000 400,000 7.500% Senior Notes 400,274 450,000 8.750% Senior Notes 500,000 — 3.125% Convertible Senior Notes 400,000 — Total long-term debt 2,800,274 2,425,000 Unamortized deferred financing costs and discounts(1) (55,562) (34,086) Long-term debt, net $ 2,744,712 $ 2,390,914 ________________________________________ (1) Includes $30.4 million and $20.8 million of unamortized deferred financing costs related to the Facility, $14.1 million and $13.3 million of unamortized deferred financing costs and discounts related to the Senior Notes, and $$11.1 million and nil of unamortized deferred financing costs related to the 3.125% Convertible Senior Notes as of December 31, 2024 and December 31, 2023, respectively. Facility The Facility supports our oil and gas exploration, appraisal and development programs and corporate activities. The amount of funds available to be borrowed under the Facility, also known as the borrowing base amount, is determined every March and September. The borrowing base amount is based on the sum of the net present values of net cash flows and relevant capital expenditures reduced by certain percentages as well as value attributable to certain assets’ reserves and/or resources in the Jubilee and TEN Fields in Ghana and the Ceiba Field and Okume Complex in Equatorial Guinea. In April 2024, in conjunction with the Spring borrowing base redetermination, the Company executed an amendment and restatement of the Facility. The amendment and restatement included the following material changes: an increase in the Facility size and borrowing base capacity to $1.35 billion (from $1.25 billion), an increase in the interest margin by 0.25% or 0.50%, depending on the length of time that has passed from the date the Facility was entered into, and an extension in the tenor by approximately three years (final maturity date now occurs December 31, 2029). The amended Facility size and borrowing base capacity of approximately $1.35 billion was capped by total commitments of approximately $1.21 billion as of June 30, 2024. As part of the amendment and restatement, the Company recognized a loss on debt modifications and extinguishments of approximately $22.0 million during the second quarter of 2024. In September 2024, we added two new lenders to the Facility syndicate, increasing total commitments by approximately $145.0 million to the full Facility size and borrowing base capacity of $1.35 billion. In October 2024, during the Fall 2024 borrowing base redetermination, the Company’s lending syndicate approved a borrowing base of $1.35 billion. As of December 31, 2024, borrowings under the Facility totaled $900.0 million and the undrawn availability under the Facility was $450 million. When our net leverage ratio exceeds 2.50x, we are required under the Facility to maintain a restricted cash balance that is sufficient to meet the payment of interest and fees for the next six-month period on the 7.125% Senior Notes, the 7.750% Senior Notes, the 7.500% Senior Notes, the 8.750% Senior Notes and the 3.125% Convertible Senior Notes or the Facility, whichever is greater. As of December 31, 2024, our net leverage ratio was 2.54x, partially due to pre-production operating costs associated with the GTA Phase 1 project. Our next financial covenant assessment date is March 31, 2025, after which date we could be required to restrict approximately $66.0 million in cash as required under the terms of the Facility unless otherwise waived by the lenders. As of December 31, 2023 our net leverage ratio was below 2.50x. Interest on the Facility is the aggregate of the applicable margin (4.00% to 5.50%, depending on the length of time that has passed from the date the Facility was entered into), plus the term SOFR reference rate administered by CME Group Benchmark Administration Limited for the relevant period published. Interest is payable on the last day of each interest period (and, if the interest period is longer than six months, on the dates falling at six-month intervals after the first day of the interest period). We pay commitment fees on the undrawn and unavailable portion of the total commitments, if any. Commitment fees are equal to 30% per annum of the then-applicable respective margin when a commitment is available for utilization and, equal to 20% per annum of the then-applicable respective margin when a commitment is not available for utilization. We recognize interest expense in accordance with ASC 835—Interest, which requires interest expense to be recognized using the effective interest method. We determined the effective interest rate based on the estimated level of borrowings under the Facility. The Facility provides a revolving credit and letter of credit facility. The availability period for the revolving credit facility expires one month prior to the final maturity date. The letter of credit facility expires on the final maturity date. The available facility amount is subject to borrowing base constraints and, beginning on April 1, 2027, outstanding borrowings will be constrained by an amortization schedule. The Facility has a final maturity date of December 31, 2029. As of December 31, 2024, we had no letters of credit issued under the Facility. We have the right to cancel all the undrawn commitments under the amended and restated Facility. If an event of default exists under the Facility, the lenders can accelerate the maturity and exercise other rights and remedies, including the enforcement of security granted pursuant to the Facility over certain assets held by our subsidiaries. We were in compliance with the financial covenants below contained in the Facility as of September 30, 2024 (the most recent assessment date), which requires the maintenance of: • the field life cover ratio (as defined in the glossary), not less than 1.50x; and • the loan life cover ratio (as defined in the glossary), not less than 1.10x through September 30, 2027 and 1.30x after September 30, 2027; and • the interest cover ratio (as defined in the glossary), not less than 2.25x; and • the debt cover ratio (as defined in the glossary), not more than 3.50x. The Facility contains customary cross default provisions. Corporate Revolver On March 31, 2022, we refinanced the Corporate Revolver by replacing it with a new revolving credit facility agreement with a total size of $250 million and a maturity date of December 31, 2024. In April 2024, in connection with the amendment and restatement of the Facility, we amended the Corporate Revolver reducing the borrowing capacity from $250.0 million to $165.0 million. In October 2024, pursuant to a voluntary cancellation notice sent by the Company, the Corporate Revolver was terminated. 7.125% Senior Notes due 2026 In April 2019, the Company issued $650.0 million of 7.125% Senior Notes and received net proceeds of approximately $640.0 million after deducting commissions and other expenses. We used the net proceeds to redeem all of the previously issued 7.875% Senior Secured Notes due 2021, repay a portion of the outstanding indebtedness under the Corporate Revolver and pay fees and expenses related to the redemption, repayment and the issuance of the 7.125% Senior Notes. The 7.125% Senior Notes mature on April 4, 2026. We will pay interest in arrears on the 7.125% Senior Notes each April 4 and October 4, commencing on October 4, 2019. The 7.125% Senior Notes are senior, unsecured obligations of Kosmos Energy Ltd. and rank equal in right of payment with all of its existing and future senior indebtedness (including all borrowings under the 7.750% Senior Notes, the 7.500% Senior Notes, the 8.750% Senior Notes and the 3.125% Convertible Senior Notes) and rank effectively junior in right of payment to all of its existing and future secured indebtedness (including all borrowings under the Facility). The 7.125% Senior Notes are guaranteed on a senior, unsecured basis by certain subsidiaries owning the Company's Gulf of America assets, and on a subordinated, unsecured basis by certain subsidiaries that borrow under, or guarantee, the Facility and that guarantee the 7.750% Senior Notes, the 7.500% Senior Notes, the 8.750% Senior Notes and the 3.125% Convertible Senior Notes. On September 24, 2024, the Company completed the repurchase of an aggregate principal amount of $400.0 million of the 7.125% Senior Notes pursuant to the Company’s cash tender offers for portions of the 7.125% Senior Notes, the 7.750% Senior Notes, and the 7.500% Senior Notes announced on September 9, 2024 (the “Tender Offers”). The 7.125% Senior Notes contain customary cross default provisions. On or after April 4, 2022, the Company may redeem all or a part of the 7.125% Senior Notes at the redemption prices (expressed as percentages of principal amount) set forth below plus accrued and unpaid interest: Year Percentage On or after April 4, 2022 103.563 % On or after April 4, 2023 101.781 % On or after April 4, 2024 100.000 % We may also redeem the 7.125% Senior Notes in whole, but not in part, at any time if changes in tax laws impose certain withholding taxes on amounts payable on the 7.125% Senior Notes at a price equal to the principal amount of the 7.125% Senior Notes plus accrued interest and additional amounts, if any, as may be necessary so that the net amount received by each holder after any withholding or deduction on payments of the 7.125% Senior Notes will not be less than the amount such holder would have received if such taxes had not been withheld or deducted. Upon the occurrence of a change of control triggering event as defined under the 7.125% Senior Notes indenture, the Company will be required to make an offer to repurchase the 7.125% Senior Notes at a repurchase price equal to 101% of the principal amount, plus accrued and unpaid interest to, but excluding, the date of repurchase. If we sell assets, under certain circumstances outlined in the 7.125% Senior Notes indenture, we will be required to use the net proceeds to make an offer to purchase the 7.125% Senior Notes at an offer price in cash in an amount equal to 100% of the principal amount of the 7.125% Senior Notes, plus accrued and unpaid interest to, but excluding, the repurchase date. The 7.125% Senior Notes indenture restricts the ability of the Company and its restricted subsidiaries to, among other things: incur or guarantee additional indebtedness, create liens, pay dividends or make distributions in respect of capital stock, purchase or redeem capital stock, make investments or certain other restricted payments, sell assets, enter into agreements that restrict the ability of the Company’s subsidiaries to make dividends or other payments to the Company, enter into transactions with affiliates, or effect certain consolidations, mergers or amalgamations. These covenants are subject to a number of important qualifications and exceptions. Certain of these covenants will be terminated if the 7.125% Senior Notes are assigned an investment grade rating by both Standard & Poor’s Rating Services and Fitch Ratings Inc. and no default or event of default has occurred and is continuing. The 7.125% Senior Notes contain customary cross default provisions. 7.750% Senior Notes due 2027 In October 2021, the Company issued $400.0 million of 7.750% Senior Notes and received net proceeds of approximately $395.0 million after deducting fees. We used the net proceeds, together with cash on hand, to refinance the $400.0 million Bridge Notes (which were issued during the fourth quarter of 2021 in connection with the completion of the acquisition of Anadarko WCTP) and to pay expenses related to the issuance of the 7.750% Senior Notes. The 7.750% Senior Notes mature on May 1, 2027. Interest is payable in arrears each May 1 and November 1, commencing on May 1, 2022. The 7.750% Senior Notes are senior, unsecured obligations of Kosmos Energy Ltd. and rank equal in right of payment with all of its existing and future senior indebtedness (including all borrowings under the 7.125% Senior Notes, the 7.500% Senior Notes, the 8.750% Senior Notes and the 3.125% Convertible Senior Notes) and rank effectively junior in right of payment to all of its existing and future secured indebtedness (including all borrowings under the Facility). The 7.750% Senior Notes are guaranteed on a senior, unsecured basis by certain subsidiaries owning the Company's Gulf of America assets, and on a subordinated, unsecured basis by certain subsidiaries that borrow under, or guarantee, the Facility and that guarantee the 7.125% Senior Notes, the 7.500% Senior Notes, the 8.750% Senior Notes and the 3.125% Convertible Senior Notes. On September 24, 2024, the Company completed the repurchase of an aggregate principal amount of $50.0 million of the 7.750% Senior Notes pursuant to the Tender Offers. The 7.750% Senior Notes contain customary cross default provisions. On or after November 1, 2023, the Company may redeem all or a part of the 7.750% Senior Notes at the redemption prices (expressed as percentages of principal amount) set forth below plus accrued and unpaid interest: Year Percentage On or after November 1, 2023 103.875 % On or after November 1, 2024 101.938 % On or after November 1, 2025 100.000 % We may also redeem the 7.750% Senior Notes in whole, but not in part, at any time if changes in tax laws impose certain withholding taxes on amounts payable on the 7.750% Senior Notes at a price equal to the principal amount of the 7.750% Senior Notes plus accrued interest and additional amounts, if any, as may be necessary so that the net amount received by each holder after any withholding or deduction on payments of the 7.750% Senior Notes will not be less than the amount such holder would have received if such taxes had not been withheld or deducted. Upon the occurrence of a change of control triggering event as defined under the 7.750% Senior Notes indenture, the Company will be required to make an offer to repurchase the 7.750% Senior Notes at a repurchase price equal to 101% of the principal amount, plus accrued and unpaid interest to, but excluding, the date of repurchase. If we sell assets, under certain circumstances outlined in the 7.750% Senior Notes indenture, we will be required to use the net proceeds to make an offer to purchase the 7.750% Senior Notes at an offer price in cash in an amount equal to 100% of the principal amount of the 7.750% Senior Notes, plus accrued and unpaid interest to, but excluding, the repurchase date. The 7.750% Senior Notes indenture restricts the ability of the Company and its restricted subsidiaries to, among other things: incur or guarantee additional indebtedness, create liens, pay dividends or make distributions in respect of capital stock, purchase or redeem capital stock, make investments or certain other restricted payments, sell assets, enter into agreements that restrict the ability of the Company's subsidiaries to make dividends or other payments to the Company, enter into transactions with affiliates, or effect certain consolidations, mergers or amalgamations. These covenants are subject to a number of important qualifications and exceptions. Certain of these covenants will be terminated if the 7.750% Senior Notes are assigned an investment grade rating by both Standard & Poor’s Rating Services and Fitch Ratings Inc. and no default or event of default has occurred and is continuing. The 7.750% Senior Notes contain customary cross default provisions. 7.500% Senior Notes due 2028 In March 2021, the Company issued $450.0 million of 7.500% Senior Notes and received net proceeds of approximately $444.4 million after deducting fees. We used the net proceeds to repay outstanding indebtedness under the Corporate Revolver and the Facility, to pay expenses related to the issuance of the 7.500% Senior Notes and for general corporate purposes. The 7.500% Senior Notes mature on March 1, 2028. Interest is payable in arrears each March 1 and September 1, commencing on September 1, 2021. The 7.500% Senior Notes are senior, unsecured obligations of Kosmos Energy Ltd. and rank equal in right of payment with all of its existing and future senior indebtedness (including all borrowings under the 7.125% Senior Notes, the 7.750% Senior Notes, the 8.750% Senior Notes and the 3.125% Convertible Senior Notes) and rank effectively junior in right of payment to all of its existing and future secured indebtedness (including all borrowings under the Facility). The 7.500% Senior Notes are guaranteed on a senior, unsecured basis by certain subsidiaries owning the Company's Gulf of America assets, and on a subordinated, unsecured basis by certain subsidiaries that borrow under, or guarantee, the Facility and that guarantee the 7.125% Senior Notes, the 7.750% Senior Notes, the 8.750% Senior Notes and the 3.125% Convertible Senior Notes. On September 24, 2024, the Company completed the repurchase of an aggregate principal amount of approximately $49.7 million of the 7.500% Senior Notes pursuant to the Tender Offers. The 7.500% Senior Notes contain customary cross default provisions. On or after March 1, 2024, the Company may redeem all or a part of the 7.500% Senior Notes at the redemption prices (expressed as percentages of principal amount) set forth below plus accrued and unpaid interest: Year Percentage On or after March 1, 2024 103.750 % On or after March 1, 2025 101.875 % On or after March 1, 2026 100.000 % We may also redeem the 7.500% Senior Notes in whole, but not in part, at any time if changes in tax laws impose certain withholding taxes on amounts payable on the 7.500% Senior Notes at a price equal to the principal amount of the 7.500% Senior Notes plus accrued interest and additional amounts, if any, as may be necessary so that the net amount received by each holder after any withholding or deduction on payments of the 7.500% Senior Notes will not be less than the amount such holder would have received if such taxes had not been withheld or deducted. Upon the occurrence of a change of control triggering event as defined under the 7.500% Senior Notes indenture, the Company will be required to make an offer to repurchase the 7.500% Senior Notes at a repurchase price equal to 101% of the principal amount, plus accrued and unpaid interest to, but excluding, the date of repurchase. If we sell assets, under certain circumstances outlined in the 7.500% Senior Notes indenture, we will be required to use the net proceeds to make an offer to purchase the 7.500% Senior Notes at an offer price in cash in an amount equal to 100% of the principal amount of the 7.500% Senior Notes, plus accrued and unpaid interest to, but excluding, the repurchase date. The 7.500% Senior Notes indenture restricts the ability of the Company and its restricted subsidiaries to, among other things: incur or guarantee additional indebtedness, create liens, pay dividends or make distributions in respect of capital stock, purchase or redeem capital stock, make investments or certain other restricted payments, sell assets, enter into agreements that restrict the ability of the Company’s subsidiaries to make dividends or other payments to the Company, enter into transactions with affiliates, or effect certain consolidations, mergers or amalgamations. These covenants are subject to a number of important qualifications and exceptions. Certain of these covenants will be terminated if the 7.500% Senior Notes are assigned an investment grade rating by both Standard & Poor’s Rating Services and Fitch Ratings Inc. and no default or event of default has occurred and is continuing. The 7.500% Senior Notes contain customary cross default provisions. 8.750% Senior Notes due 2031 In September 2024, the Company issued $500.0 million of 8.750% Senior Notes and received net proceeds of approximately $494.9 million after deducting fees. We used the net proceeds, together with cash on hand, to fund the Tender Offers and pay expenses related to the issuance of the 8.750% Senior Notes. The 8.750% Senior Notes mature on October 1, 2031. Interest is payable in arrears each April 1 and October 1, commencing on April 1, 2025. The 8.750% Senior Notes are senior, unsecured obligations of Kosmos Energy Ltd. and rank equal in right of payment with all of its existing and future senior indebtedness (including all borrowings under the 7.125% Senior Notes, the 7.750% Senior Notes, the 7.500% Senior Notes and the 3.125% Convertible Senior Notes) and rank effectively junior in right of payment to all of its existing and future secured indebtedness (including all borrowings under the Facility). The 8.750% Senior Notes are guaranteed on a senior, unsecured basis by certain subsidiaries owning the Company’s Gulf of America assets and on a subordinated, unsecured basis by certain subsidiaries that borrow under, or guarantee, the Facility and that guarantee the 7.125% Senior Notes, the 7.750% Senior Notes, the 7.500% Senior Notes and the 3.125% Convertible Senior Notes. The 8.750% Senior Notes contain customary cross default provisions. At any time prior to October 1, 2027, and subject to certain conditions, the Company may, on one or more occasions, redeem up to 40% of the original principal amount of the 8.750% Senior Notes with an amount not to exceed the net cash proceeds of certain equity offerings at a redemption price of 108.750% of the outstanding principal amount of the 8.750% Senior Notes, together with accrued and unpaid interest and premium, if any, to, but excluding, the date of redemption. Additionally, at any time prior to October 1, 2027, the Company may, on any one or more occasions, redeem all or part of the 8.750% Senior Notes at a redemption price equal to 100%, plus any accrued and unpaid interest, and plus a “make-whole” premium. On and after October 1, 2027, the Company may redeem all or part of the 8.750% Senior Notes at the following redemption prices (expressed as a percentage of principal amount), plus accrued and unpaid interest, if any, on the notes redeemed during the twelve-month period indicated beginning on October 1 of the years indicated below: Year Percentage 2027 104.375 % 2028 102.188 % 2029 and thereafter 100.000 % We may also redeem the 8.750% Senior Notes in whole, but not in part, at any time if changes in tax law impose certain withholding taxes on amounts payable of the 8.750% Senior Notes at a price equal to the principal amount of the 8.750% Senior Notes plus accrued interest and additional amounts, if any, as may be necessary so that the net amount received by each holder after any withholding or deduction on payments of the 8.750% Senior Notes will not be less than the amount such holder would have received if such taxes had not been withheld or deducted. Upon the occurrence of a change of control triggering event as defined under the 8.750% Senior Notes indenture, the Company will be required to make an offer to repurchase the 8.750% Senior Notes at a repurchase price equal to 101% of the principal amount, plus accrued and unpaid interest to, but excluding, the date of repurchase. If we sell assets, under certain circumstances outlined in the 8.750% Senior Notes indenture, we will be required to use the net proceeds to make an offer to purchase the 8.750% Senior Notes at an offer price in cash in an amount equal to 100% of the principal amount of the 8.750% Senior Notes, plus accrued an unpaid interest to, but excluding, the repurchase date. The 8.750% Senior Notes indenture restricts the ability of the Company and its restricted subsidiaries to, among other things: incur or guarantee additional indebtedness, create liens, pay dividends or make distributions in respect of capital stock, purchase or redeem capital stock, make investments or certain other restricted payments, sell assets, enter into agreements that restrict the ability of the Company’s subsidiaries to make dividends or other payments to the Company, enter into transactions with affiliates, or effect certain consolidations, mergers or amalgamations. Certain of these covenants will be terminated if the 8.750% Senior Notes are assigned an investment grade rating by both Standard & Poor’s Rating Services and Fitch Ratings Inc. and no default or event of default has occurred and is continuing. 3.125% Convertible Senior Notes due 2030 In March 2024, the Company issued $400.0 million of 3.125% Convertible Senior Notes (the “3.125% Convertible Senior Notes”) and received net proceeds of $390.4 million after deducting fees. The 3.125% Convertible Senior Notes mature on March 15, 2030, unless earlier converted, redeemed or repurchased. Interest is payable in arrears each March 15 and September 15, commencing September 15, 2024. The 3.125% Convertible Senior Notes are senior, unsecured obligations of Kosmos Energy Ltd. and rank equal in right of payment with all of its existing and future senior indebtedness (including all borrowings under the 7.125% Senior Notes, the 7.750% Senior Notes, the 7.500% Senior Notes and the 8.750% Senior Notes) and rank effectively junior in right of payment to all of its existing and future secured indebtedness (including all borrowings under the Facility, to the extent of the value of the assets securing such indebtedness). The 3.125% Convertible Senior Notes are guaranteed on a senior, unsecured basis by certain of our existing subsidiaries that guarantee on a senior basis the 7.125% Senior Notes, the 7.750% Senior Notes, the 7.500% Senior Notes and the 8.750% Senior Notes, and, in certain circumstances, certain of our other existing or future subsidiaries. The 3.125% Convertible Senior Notes are guaranteed on a subordinated, unsecured basis by certain or existing subsidiaries that borrow under or guarantee the Facility and guarantee on a subordinated basis the 7.125% Senior Notes, the 7.750% Senior Notes, the 7.500% Senior Notes and the 8.750% Senior Notes, and, in certain circumstances, certain of our other existing or future subsidiaries. Holders of the 3.125% Convertible Senior Notes may convert all or any portion of their 3.125% Convertible Senior Notes at their option at any time prior to the close of business on the business day immediately preceding December 15, 2029 only under the following circumstances: • during any calendar quarter commencing after the calendar quarter ending on June 30, 2024 (and only during such calendar quarter), if the last reported sale price of our common stock for at least 20 trading days (whether or not consecutive) during a period of 30 consecutive trading days ending on, and including, the last trading day of the immediately preceding calendar quarter is greater that or equal to 130% of the conversion price on each applicable trading day; • during the five five • if we call any or all of the 3.125% Convertible Senior Notes for redemption, the 3.125% Convertible Senior Notes called (or deemed called) for redemption may be converted at any time prior to the close of business on the second scheduled trading day immediately preceding the redemption date; or • upon the occurrence of certain specified corporate events. On or after December 15, 2029 until the close of business on the second scheduled trading day immediately preceding the maturity date, holders may convert at any time all or a portion of their 3.125% Convertible Senior Notes at the option of the holder. The conversion rate for the 3.125% Convertible Senior Notes is initially 142.4501 share of common stock per $1,000 principal amount of 3.125% Convertible Senior Notes (which is equivalent to an initial conversion price of approximately $7.02 per share of our common stock), subject to adjustments. Upon conversion, we will pay cash up to the aggregate principal amount of the 3.125% Convertible Senior Notes to be converted and pay or deliver, as the case may be, cash, shares of our common stock or a combination of cash and shares of our common stock, at our election in respect of the remainder, if any, of our conversion obligation in excess of the aggregate principal amount of the 3.125% Convertible Senior Notes being converted. The amount of cash and shares of our common stock, if any, due upon conversion will be based on a daily conversion value calculated on a proportionate basis for each trading day in a 40 consecutive trading day observation period. In addition, following certain corporate events that occur prior to the maturity date or if we deliver a notice of redemption, we will, in certain circumstances, increase the conversion date for a holder who elects to convert its 3.125% Convertible Senior Notes in connection with such a corporate event or to convert its 3.125% Convertible Senior Notes called (or deemed called) for redemption in connection with such notice of redemption, as the cause may be. Other than in connection with certain tax law changes, we may not redeem the notes prior to March 22, 2027. We may redeem for cash all or any portion of the 3.125% Convertible Senior Notes, at our option, on or after March 22, 2027 and prior to the 41st scheduled trading day immediately preceding the maturity date, if the last reported sale price of our common stock has been at least 130% of the conversion price then in effect for at least 20 trading days (whether or not consecutive), including the trading day immediately preceding the date on which the Company provides notice of redemption, during an 30 day consecutive trading day period ending on, and including, the trading day immediately preceding the date on which we provide the related notice of redemption, at a redemption price equal to 100% of the principal amount of the 3.125% Convertible Senior Notes to be redeemed, plus accrued and unpaid interest to, but excluding, the redemption date. We are not required to redeem or retire the 3.125% Convertible Senior Notes periodically. We may not elect to redeem less than all of the outstanding 3.125% Convertible Senior Notes unless at least $75.0 million aggregate principal amount of 3.125% Convertible Senior Notes are outstanding and not subject to redemption as of the time we send the related redemption notice. The 3.125% Convertible Senior Notes indenture contains customary terms and covenants. The Company recorded the 3.125% Convertible Senior Notes, including the debt itself and all embedded derivatives, at cost less debt issuance costs of $9.6 million and has presented the 3.125% Convertible Senior Notes as a single financial instrument in Long-term debt, net in our consolidated balance sheet. No portion of the embedded derivative required bifurcation from the host debt contract. As of December 31, 2024, the effective annual interest rate on the 3.125% Convertible Senior Notes is approximately 3.70%, including amortization of debt issuance costs. Capped Call Transactions In connection with the issuance of the 3.125% Convertible Senior Notes, the Company used $49.8 million of the net proceeds from the issuance of the 3.125% Convertible Senior Notes to enter into capped call transactions (the “Capped Call Transactions”). The Capped Call Transactions are generally expected to reduce potential dilution to holders of our common stock upon any conversion of the 3.125% Convertible Senior Notes and/or offset any cash payments that we are required to make in excess of the principal amount of any 3.125% Convertible Senior Notes that are converted, as the case may be, with such reduction and/or offset subject to a cap. The Capped Call Transactions have an initial cap price of $10.80 per share, which represents a premium of 100% over the last reported sale price of our common stock on March 5, 2024, and is subject to certain adjustments under the terms of the Capped Call Transactions. The Capped Call Transactions cover, initially, the number of shares of our common stock underlying the 3.125% Convertible Senior Notes, subject to anti-dilution adjustments substantially similar to those applicable to the conversion rate of the 3.125% Convertible Senior Notes. The Capped Call Transactions qualify for a derivative scope exception as they are indexed to our common stock and are not required to be accounted for as a separate derivative. Consequently, the Capped Call Transactions have been included as a net reduction to additional-paid-in-capital within stockholders’ equity in our consolidated balance sheet and do not require subsequent remeasurement. Principal Debt Repayments At December 31, 2024, the estimated repayments of debt during the five fiscal year periods and thereafter are a

Derivative Financial Instrument

Derivative Financial Instruments	12 Months Ended
	Dec. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	Derivative Financial Instruments We use financial derivative contracts to manage exposures to commodity price and interest rate fluctuations. We do not hold or issue derivative financial instruments for trading purposes. We manage market and counterparty credit risk in accordance with our policies and guidelines. In accordance with these policies and guidelines, our management determines the appropriate timing and extent of derivative transactions. We have included an estimate of non-performance risk in the fair value measurement of our derivative contracts as required by ASC 820—Fair Value Measurements and Disclosures. Oil Derivative Contracts The following table sets forth the volumes in barrels underlying the Company’s outstanding oil derivative contracts and the weighted average prices per Bbl for those contracts as of December 31, 2024. Volumes and weighted average prices are net of any offsetting derivative contracts entered into. Weighted Average Price per Bbl Term Type of Contract Index MBbl Net Deferred Premium Payable/(Receivable) Swap Sold Put Floor Ceiling 2025: Jan - Jun Two-way collars Dated Brent 2,000 0.50 — — 70.00 85.00 Jan - Jun Swaps Dated Brent 2,000 — 75.48 — — — Jan - Dec Two-way collars Dated Brent 2,000 1.00 — — 70.00 85.00 ______________________________________ In January 2025, we entered into Dated Brent three-way collar contracts for 2.0 MMBbl from January 2025 through December 2025 with a sold put price of $55.00 per barrel, a floor price of $70.00 per barrel and a ceiling price of $85.00 per barrel. Interest Rate Derivative Contracts The following table summarized our open interest rate swaps whereby we pay a fixed rate of interest and the counterparty pays a variable SOFR-based rate as of December 31, 2024: Weighted Average Term Type of Contract Floating Rate Notional Fixed Rate (In Thousands) Jan - Dec 2025 Swap 1-Month TERM SOFR $ 500,000 3.645 % See Note 10—Fair Value Measurements for additional information regarding the Company’s derivative instruments. The following tables disclose the Company’s derivative instruments as of December 31, 2024 and 2023 and gain/(loss) from derivatives during the years ended December 31, 2024, 2023 and 2022. Estimated Fair Value Asset (Liability) December 31, Type of Contract Balance Sheet Location 2024 2023 (In thousands) Derivatives not designated as hedging instruments: Derivative assets: Commodity Derivatives assets—current $ 6,714 $ 8,346 Provisional oil sales Receivables: Oil sales 2,242 — Interest rate Derivatives assets—current 2,202 — Commodity Derivatives assets—long-term 512 1,594 Derivative liabilities: Commodity Derivatives liabilities—current — (3,103) Provisional oil sales Receivables: Oil sales — (72) Total derivatives not designated as hedging instruments $ 11,670 $ 6,765 Amount of Gain/(Loss) Years Ended December 31, Type of Contract Location of Gain/(Loss) 2024 2023 2022 (In thousands) Derivatives not designated as hedging instruments: Provisional oil sales Oil and gas revenue $ (4,850) $ (17,221) $ (14,573) Commodity Derivatives, net (12,099) (11,128) (260,892) Interest rate Interest expense 2,202 — — Total derivatives not designated as hedging instruments $ (14,747) $ (28,349) $ (275,465) Offsetting of Derivative Assets and Derivative Liabilities Our derivative instruments which are subject to master netting arrangements with our counterparties only have the right of offset when there is an event of default. As of December 31, 2024 and 2023, there was not an event of default and, therefore, the associated gross asset or gross liability amounts related to these arrangements are presented on the consolidated balance sheets.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2024
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements In accordance with ASC 820—Fair Value Measurements, fair value measurements are based upon inputs that market participants use in pricing an asset or liability, which are classified into two categories: observable inputs and unobservable inputs. Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company’s own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. We prioritize the inputs used in measuring fair value into the following fair value hierarchy: • Level 1 — quoted prices for identical assets or liabilities in active markets. • Level 2 — quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs derived principally from or corroborated by observable market data by correlation or other means. • Level 3 — unobservable inputs for the asset or liability. The fair value input hierarchy level to which an asset or liability measurement in its entirety falls is determined based on the lowest level input that is significant to the measurement in its entirety. The following tables present the Company’s assets and liabilities that are measured at fair value on a recurring basis as of December 31, 2024 and 2023, for each fair value hierarchy level: Fair Value Measurements Using: Quoted Prices in Active Markets for Identical Assets Significant Other Significant Unobservable Inputs (Level 1) (Level 2) (Level 3) Total (In thousands) December 31, 2024 Assets: Commodity derivatives $ — $ 7,226 $ — $ 7,226 Provisional oil sales — 2,242 — 2,242 Interest rate derivatives — 2,202 — 2,202 Decommissioning trust fund: Debt securities — 10,653 — 10,653 Total $ — $ 22,323 $ — $ 22,323 December 31, 2023 Assets: Commodity derivatives $ — $ 9,940 $ — $ 9,940 Liabilities: Commodity derivatives — (3,103) — (3,103) Provisional oil sales — (72) — (72) Total $ — $ 6,765 $ — $ 6,765 The book values of cash and cash equivalents and restricted cash approximate fair value based on Level 1 inputs. Joint interest billings, oil sales and other receivables, and accounts payable and accrued liabilities approximate fair value due to the short‑term nature of these instruments. Our long‑term receivables, after any allowances for credit losses, and other long-term assets approximate fair value. The estimates of fair value of these items are based on Level 2 inputs. Commodity Derivatives Our commodity derivatives represent crude oil collars, put options, call options and swaps for notional barrels of oil at fixed Dated Brent oil prices. The values attributable to our oil derivatives are based on (i) the contracted notional volumes, (ii) independent active futures price quotes for the respective index, (iii) a credit‑adjusted yield curve applicable to each counterparty by reference to the credit default swap (“CDS”) market and (iv) an independently sourced estimate of volatility for the respective index. The volatility estimate was provided by certain independent brokers who are active in buying and selling oil options and was corroborated by market‑quoted volatility factors. The deferred premium is included in the fair market value of the commodity derivatives. See Note 9—Derivative Financial Instruments for additional information regarding the Company’s derivative instruments. Provisional Oil Sales The value attributable to provisional oil sales derivative is based on (i) the sales volumes and (ii) the difference in the independent active futures price quotes for the respective index over the term of the pricing period designated in the sales contract and the spot price on the lifting date. Interest Rate Derivatives Our interest rate derivatives consist of interest rate swaps, whereby the Company pays a fixed rate of interest and the counterparty pays a variable SOFR-based rate. The values attributable to the Company’s interest rate derivative contracts are based on (i) the contracted notional amounts, (ii) SOFR yield curves provided by independent third parties and corroborated with forward active market-quoted SOFR yield curves and (iii) a credit-adjusted yield curve as applicable to each counterparty by reference to the CDS market. Decommissioning Trust Fund In April 2024, a decommissioning trust agreement with the Jubilee unit partners to cash fund future retirement costs associated with the Jubilee Field was finalized. Each partner will contribute annually to the trust in proportion to its respective paying interest of the estimated future dismantlement, abandonment and restoration costs associated with the decommissioning of the Jubilee Field. Contributions to the trust are used by the trustee of the fund, the Bank of Ghana, to purchase and sell authorized securities at the direction of the Jubilee unit partners. As of December 31, 2024, the investments held in the decommissioning trust fund are US Treasury debt securities. We have classified the investments as trading securities and recorded such investments at their fair market value as a long-term investment in our consolidated balance sheet using observable inputs including Kosmos’ share of the fund and broker/dealer bid/ask prices of the investments held by the fund at December 31, 2024. Contributions made to the decommissioning trust are reported as investing activities in our consolidated statement of cash flows. All realized and unrealized gains and losses resulting from the sales and maturities or changes in fair value of the securities are recognized in Other income, net. For the year ended December 31, 2024, we contributed $11.5 million to the decommissioning trust fund. The following table summarizes the cost and fair value, purchases, proceeds from the sales and maturities, and the unrealized gains (losses) for Kosmos’ portion of the investments in debt securities held by the decommissioning trust at December 31, 2024 and 2023: January 1, December 31, Type of Security Cost Purchases Net Proceeds (1) Unrealized Gain (Loss) Estimated Fair Value 2024 (In thousands) Debt securities $ — $ 10,708 $ — $ (55) $ 10,653 Cash and cash equivalents — 752 101 — 853 Total $ — $ 11,460 $ 101 $ (55) $ 11,506 2023 Debt securities $ — $ — $ — $ — $ — Cash and cash equivalents — — — — — Total $ — $ — $ — $ — $ — (1) Net proceeds includes realized gains or losses, interest income, and fees. The following table presents the costs and fair values of investments in debt securities held in the decommissioning trust fund according to the contractual maturities at December 31, 2024 and 2023: December 31, 2024 December 31, 2023 Cost Estimated Fair Value Cost Estimated Fair Value (In thousands) Less than 5 years $ 10,708 $ 10,653 $ — $ — 5 years to 10 years — — — — Due after 10 years — — — — Total $ 10,708 $ 10,653 $ — $ — Debt The following table presents the carrying values and fair values at December 31, 2024 and 2023: December 31, 2024 December 31, 2023 Carrying Value Fair Value Carrying Value Fair Value (In thousands) 7.125% Senior Notes $ 249,315 $ 246,565 $ 646,912 $ 622,824 7.750% Senior Notes 347,910 339,927 396,718 374,764 7.500% Senior Notes 397,672 379,404 446,291 412,461 8.750% Senior Notes 494,997 470,965 — — 3.125% Convertible Senior Notes 391,603 332,792 — — Facility 900,000 900,000 925,000 925,000 Total $ 2,781,497 $ 2,669,653 $ 2,414,921 $ 2,335,049 The carrying values of our 7.125% Senior Notes, 7.750% Senior Notes, 7.500% Senior Notes, 8.750% Senior Notes and 3.125% Convertible Senior Notes represent the principal amounts outstanding less unamortized discounts. The fair values of our 7.125% Senior Notes, 7.750% Senior Notes, 7.500% Senior Notes, 8.750% Senior Notes and 3.125% Convertible Senior Notes are based on quoted market prices, which results in a Level 1 fair value measurement. The carrying values of the Facility approximate fair value since they are subject to short-term floating interest rates that approximate the rates available to us for those periods. Nonrecurring Fair Value Measurements - Long-lived assets Certain long-lived assets are reported at fair value on a non-recurring basis on the Company's consolidated balance sheet. These long-lived assets are not measured at fair value on an ongoing basis but are subject to fair value adjustments in certain circumstances. Our long-lived assets are reviewed for impairment when changes in circumstances indicate that the carrying amount of an asset may not be recoverable. The Company calculates the estimated fair values of its long-lived assets using the income approach described in the ASC 820 — Fair Value Measurements. Significant inputs associated with the calculation of estimated discounted future net cash flows include anticipated future production, pricing estimates, capital and operating costs, market-based weighted average cost of capital, and risk adjustment factors applied to reserves. These are classified as Level 3 fair value assumptions. The Company utilizes an average of third-party industry forecasts of Dated Brent, adjusted for location and quality differentials, to determine our pricing assumptions. In order to evaluate the sensitivity of the assumptions, we analyze sensitivities to prices, production, and risk adjustment factors. No impairment of proved oil and gas properties was recognized for the year December 31, 2024. As a result of negative proved oil and gas reserve revisions at TEN, primarily driven by a change in the partnership’s development work scope for the TEN Fields and well performance, we reviewed our TEN long-lived assets for impairment at December 31, 2023, which resulted impairment charges of $222.3 million for the year ended December 31, 2023. The impairment charges resulted in a full impairment of the remaining book value of TEN reducing the carrying value of the TEN Fields to zero. As part of our impairment analysis, the average per barrel Dated Brent price of third-party industry forecasts used for purposes of determining discounted future cash flows was in the low-$80s adjusted for inflation. The expected future cash flows were discounted using a rate of approximately 10 percent which the Company believes is a market-based weighted average cost of capital for industry peers determined appropriate at the time of the valuation. As a result of a negative proved oil and gas reserve revision at TEN, primarily driven by well performance, we reviewed our TEN long-lived assets for impairment at December 31, 2022, which resulted in impairment charges of $450.0 million for the year ended December 31, 2022, reducing the carrying value of the TEN Fields to the estimated fair value of $235.7 million as of December 31, 2022. As part of our impairment analysis, the average per barrel Dated Brent price of third-party industry forecasts used for purposes of determining discounted future cash flows was in the low-$80s adjusted for inflation. We also took account of the delayed future investment in the field. The expected future cash flows were discounted using a rate of approximately 10 percent which the Company believes is a market-based weighted average cost of capital for industry peers determined appropriate at the time of the valuation. These impairment charges are included in Impairments of long-lived assets on the consolidated statement of operations. If we experience material declines in oil pricing expectations, increases in our estimated future expenditures o r a decrease in

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2024
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The following table summarizes the changes in the Company’s asset retirement obligations: December 31, 2024 2023 (In thousands) Asset retirement obligations: Beginning asset retirement obligations $ 346,786 $ 302,534 Liabilities incurred during period 23,104 16,196 Liabilities settled during period (1,675) (13,082) Revisions in estimated retirement obligations 4,953 11,527 Accretion expense 33,843 29,611 Ending asset retirement obligations $ 407,011 $ 346,786 The asset retirement obligations reflect the estimated present value of the amount of dismantlement, removal, site reclamation, and similar activities associated with our oil and gas properties. The Company utilizes current cost experience to estimate the expected cash outflows for retirement obligations. The Company estimates the ultimate productive life of the properties, a risk-adjusted discount rate, and an inflation factor in order to determine the current present value of this obligation. To the extent future revisions to these assumptions impact the present value of the existing asset retirement obligation, a corresponding adjustment is made to the oil and gas property balance. The liabilities incurred during 2024 are related to the infill drilling programs in the Jubilee Field in Ghana and the Ceiba and Okume Complex in Equatorial Guinea, the Winterfell development in the Gulf of America and the Greater Tortue Ahmeyim Phase 1 development project in Mauritania and Senegal. The revisions in estimated retirement obligations during 2024 and 2023 are related to changes in the estimated timing, scopes of work and costs.

Equity-based Compensation

Equity-based Compensation	12 Months Ended
	Dec. 31, 2024
Share-Based Payment Arrangement [Abstract]
Equity-based Compensation	Equity‑based Compensation Restricted Stock Awards and Restricted Stock Units Our Long-Term Incentive Plan (“LTIP”) provides for the granting of incentive awards in the form of stock options, stock appreciation rights, restricted stock awards, restricted stock units, among other award types. In June 2023, the Company’s stockholders approved the Amended and Restated Kosmos Energy Ltd. LTIP, which authorized an additional 17.0 million shares of common stock available for issuance under the LTIP. The LTIP as amended provides for the issuance of 78.5 million shares pursuant to awards under the LTIP. As of December 31, 2024, the Company had approximately 10.4 million shares that remain available for issuance under the LTIP. The Company granted restricted stock units with service vesting criteria and with a combination of market and service vesting criteria under the LTIP. Substantially, all of these awards vest over a three year period. Upon vesting, restricted stock units become issued and outstanding stock. The following table reflects the outstanding restricted stock units as of December 31, 2024: Service Vesting Weighted- Average Grant-Date Fair Value Market / Service Vesting Restricted Stock Units Weighted-Average Grant-Date Fair Value (In thousands) (In thousands) Outstanding at December 31, 2021: 4,696 $ 3.88 11,233 $ 5.28 Granted(1) 2,820 4.70 3,388 6.98 Forfeited(1) (147) 3.92 (389) 6.21 Vested (2,453) 4.21 (2,191) 5.98 Outstanding at December 31, 2022: 4,916 4.18 12,041 5.61 Granted(1) 2,809 7.61 3,482 12.26 Forfeited(1) (240) 5.65 (203) 8.17 Vested (2,775) 3.86 (2,950) 8.22 Outstanding at December 31, 2023: 4,710 5.77 12,370 6.59 Granted(1) 4,481 6.22 6,232 8.58 Forfeited(1) (386) 6.31 (485) 9.57 Vested (4,052) 3.02 (9,351) 3.91 Outstanding at December 31, 2024: 4,753 6.36 8,766 9.07 __________________________________ (1) The restricted stock units with a combination of market and service vesting criteria may vest between 0% and 200% of the originally granted units depending upon market performance conditions. Awards vesting over or under target shares of 100% results in additional shares granted or forfeited, respectively, in the period the market vesting criteria is determined. As of December 31, 2024, total equity‑based compensation to be recognized on unvested restricted stock units is $27.6 million over a weighted average period of 1.7 years. For restricted stock units with a combination of market and service vesting criteria, the number of common shares to be issued is determined by comparing the Company’s total shareholder return with the total shareholder return of a predetermined group of peer companies over the performance period and can vest in up to 200% of the awards granted. The grant date fair value ranged from $1.06 to $13.06 per award. The Monte Carlo simulation model utilizes multiple input variables that determined the probability of satisfying the market condition stipulated in the award grant and calculates the fair value of the award. The expected volatility utilized in the model was estimated using our historical volatility and the historical volatilities of our peer companies and ranged from 50.0% to 105.0%. The risk‑free interest rate was based on the U.S. treasury rate for a term commensurate with the expected life of the grant ranged from 0.2% to 4.1%. The expected quarterly dividends ranged from $0.00 to $0.05 commensurate with our current dividend experience. In January 2025, we granted 2.4 million service vesting restricted stock units and 3.0 million market and service vesting restricted stock units to our employees under our long-term incentive plan. We expect to recognize approximately $23.8 million of non-cash compensation expense related to these grants over the next three years. We record equity-based compensation expense in General and administrative expenses in our consolidated statement of operations equal to the grant date fair value of share‑based payments over the vesting periods of the LTIP awards. The following table summarizes certain information related to our share-based payments: Years Ended December 31, 2024 2023 2022 (In thousands) Share-based compensation expense $ 37,951 $ 42,693 $ 34,546 Total tax benefit 6,184 7,482 5,933 Net tax shortfall (windfall) (9,562) (3,201) 673 Fair value of awards vested 82,317 45,098 22,205

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2024
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes We provide for income taxes based on the laws and rates in effect in the countries in which our operations are conducted. The relationship between our pre‑tax income or loss from continuing operations and our income tax expense or benefit varies from period to period as a result of various factors which include changes in total pre‑tax income or loss, the jurisdictions in which our income (loss) is earned and the tax laws in those jurisdictions. During the year ended December 31, 2024, our net deferred tax liability decreased by approximately $52.1 million primarily as a result of a tax rate change in Equatorial Guinea (discussed below) and the timing reversal of temporary differences. During the year ended December 31, 2023, our net deferred tax liability decreased by approximately $107.6 million primarily as a result of a $222.3 million impairment related to the TEN Field, which resulted in a reduction in our deferred tax liability of $77.8 million, with the remaining $29.8 million decrease in our deferred tax liability primarily related to the timing of the reversal of temporary differences. During the year ended December 31, 2022, our net deferred tax liability decreased by approximately $242.7 million, primarily as a result of a $450.0 million impairment related to the TEN Field, which resulted in a reduction in our deferred tax liability of approximately $157.6 million, and a $44.6 million of the decrease related to closing the Tullow pre-emption transaction in March 2022 (See Note 3 - Acquisitions and Divestitures), and the remaining $40.5 million decrease in our deferred tax liability primarily related to the timing of the reversal of temporary differences. Income (loss) before income taxes is composed of the following: Years Ended December 31, 2024 2023 2022 (In thousands) United States $ (162,243) $ (88,458) $ 73,529 Foreign 512,055 460,193 263,538 Income before income taxes $ 349,812 $ 371,735 $ 337,067 The components of the provision for income taxes attributable to our income (loss) before income taxes consist of the following: Years Ended December 31, 2024 2023 2022 (In thousands) Current: United States $ (1,074) $ 865 $ 7,174 Foreign 213,209 264,910 300,829 Total current 212,135 265,775 308,003 Deferred: United States 2,933 551 84 Foreign (55,107) (108,111) (197,571) Total deferred (52,174) (107,560) (197,487) Income tax expense $ 159,961 $ 158,215 $ 110,516 Our reconciliation of income tax expense (benefit) computed by applying our statutory rate and the reported effective tax rate on income or (loss) from continuing operations is as follows: Years Ended December 31, 2024 2023 2022 (In thousands) Tax at statutory rate $ 72,167 $ 78,064 $ 70,784 Foreign income (loss) taxed at different rates 66,634 48,768 20,663 Non-deductible compensation 8,813 5,915 3,012 Non-deductible and other items 7,216 2,243 3,993 Tax shortfall (windfall) on equity-based compensation, net (11,615) (3,201) 673 Change in valuation allowance 72,179 26,426 11,391 Change in statutory tax rate (55,433) — — Total tax expense (benefit) $ 159,961 $ 158,215 $ 110,516 Effective tax rate 46 % 43 % 33 % ______________________________________ (1) The effective tax rate during the years ended December 31, 2024, 2023 and 2022, were impacted by (gains) and losses of $155.3 million, $(4.0) million and $21.0 million, respectively, incurred in jurisdictions in which we are not subject to taxes and therefore do not generate any income tax benefits or where there are valuation allowances offsetting the corresponding deferred tax assets. The effective tax rate for the United States is approximately (1%), (2%) and 10% for the years ended December 31, 2024, 2023 and 2022, respectively. The effective tax rate in the United States is impacted by the effect of non-deductible expenditures and equity-based compensation tax shortfalls and tax windfalls equal to the difference between the income tax benefit recognized for financial statement reporting purposes compared to the income tax benefit realized for tax return purposes. For the years ended December 31, 2024, 2023 and 2022, our effective tax rate in the United States is impacted by changes in valuation allowances on a portion of our deferred tax assets totaling $33.1 million, $12.1 million and $(12.3) million, respectively. The effective tax rate for Ghana is approximately 35%, 36% and 35% for the years ended December 31, 2024, 2023 and 2022, respectively. The effective tax rate in Ghana is impacted by non-deductible expenditures. The effective tax rate for our producing entity in Equatorial Guinea is approximately (68)%, 35% and 36% for the years ended December 31, 2024, 2023 and 2022, respectively, and is impacted by non-deductible expenditures. Equatorial Guinea changed the statutory rate from 35% to 25%, with an effective date of January 1, 2025. We remeasured the net deferred tax liability during the fourth quarter of 2024 which impacted the effective tax rate for the year. Our operations in other foreign jurisdictions have a 0% effective tax rate because they reside in countries with minimal activity, a 0% statutory rate, or we have incurred losses in those countries and have full valuation allowances against the corresponding net deferred tax assets. Deferred tax assets and liabilities, which are computed on the estimated income tax effect of temporary differences between financial and tax bases in assets and liabilities, are determined using the tax rates expected to be in effect when taxes are actually paid or recovered. In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. The tax effects of significant temporary differences giving rise to deferred tax assets and liabilities are as follows: December 31, 2024 2023 (In thousands) Deferred tax assets: Foreign capitalized operating expenses $ 247,306 $ 209,453 Foreign net operating losses 34,764 14,458 United States net operating losses 96,945 78,706 United States deferred interest expense 69,051 43,411 Equity compensation 11,164 10,867 Asset retirement obligation and other 98,056 78,024 Total deferred tax assets 557,286 434,919 Valuation allowance (405,831) (333,651) Total deferred tax assets, net 151,455 101,268 Deferred tax liabilities: Depletion, depreciation and amortization related to property and equipment (411,234) (420,066) Other deferred tax liabilities (48,937) (42,087) Total deferred tax liabilities (460,171) (462,153) Net deferred tax liability $ (308,716) $ (360,885) The Company has foreign net operating loss carryforwards of $128.6 million. Of these losses, we expect $70.7 million to expire in 2029 and, $58.0 million will not expire. Additionally, the Company has $461.6 million of United States net operating loss that will not expire. All of these losses currently have offsetting valuation allowances. The Company is open to tax examinations in the United States for federal income tax return years 2021 through 2023, in Ghana for income tax return years 2020 through 2023, in Equatorial Guinea for income tax return years 2019 through 2023, in the United Kingdom for income tax years 2021 through 2023, in Senegal for income tax years 2020 through 2023, and in Mauritania from 2021 through 2023. As of December 31, 2024, the Company had no material uncertain tax positions. The Company’s policy is to recognize potential interest and penalties related to income tax matters in income tax expense.

Net Income (Loss) Per Share

Net Income (Loss) Per Share	12 Months Ended
	Dec. 31, 2024
Earnings Per Share [Abstract]
Net Income (Loss) Per Share	Net Income (Loss) Per Share In the calculation of basic net income per share, participating securities are allocated earnings based on actual dividend distributions received plus a proportionate share of undistributed net income, if any. We calculate basic net income per share under the two‑class method. Diluted net income (loss) per share is calculated under both the two-class method and the treasury stock method and the more dilutive of the two calculations is presented. The computation of diluted net income (loss) per share reflects the potential dilution that could occur if all outstanding awards under our LTIP were converted into shares of common stock or resulted in the issuance of shares of common stock that would then share in the earnings of the Company. During periods in which the Company realizes a loss from continuing operations securities would not be dilutive to net loss per share and conversion into shares of common stock is assumed not to occur. Basic net income (loss) per share is computed as (i) net income (loss), (ii) less income allocable to participating securities (iii) divided by weighted average basic shares outstanding. The Company’s diluted net income (loss) per share is computed as (i) basic net income (loss), (ii) plus diluted adjustments to income allocable to participating securities (iii) divided by weighted average diluted shares outstanding. Years Ended December 31, 2024 2023 2022 (In thousands, except per share data) Numerator: Net income allocable to common stockholders $ 189,851 $ 213,520 $ 226,551 Denominator: Weighted average number of shares outstanding: Basic 470,844 459,641 455,346 Restricted stock units(1) 5,847 21,429 19,511 Diluted 476,691 481,070 474,857 Net income per share: Basic $ 0.40 $ 0.46 $ 0.50 Diluted $ 0.40 $ 0.44 $ 0.48 ______________________________________ (1) Our restricted stock units are not considered to be participating securities and, therefore, are excluded from the basic net income (loss) per share calculation. (2) For the years ended December 31, 2024, 2023 and 2022, we excluded 3.3 million, 0.0 million and 0.1 million outstanding restricted stock units, respectively, from the computations of diluted net income per share because the effect would have been anti‑dilutive.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2024
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies From time to time, we are involved in litigation, regulatory examinations and administrative proceedings primarily arising in the ordinary course of our business in jurisdictions in which we do business. Although the outcome of these matters cannot be predicted with certainty, management believes none of these matters, either individually or in the aggregate, would have a material effect upon the Company’s financial position; however, an unfavorable outcome could have a material adverse effect on our results from operations for a specific interim period or year. As of December 31, 2024, we have a commitment to drill one development well in Equatorial Guinea. In February 2019, Kosmos and BP signed Carry Advance Agreements with the national oil companies of Mauritania and Senegal, which obligate us separately to finance the respective national oil companies’ share of certain GTA Phase 1 development and production costs. Kosmos’ total share for the two agreements combined is currently estimated at approximately $370.0 million, of which $280.1 million has been incurred through December 31, 2024, excluding accrued interest. In April 2024, a decommissioning trust agreement with the Jubilee unit partners to cash fund future retirement costs associated with the Jubilee Field was finalized. The operator currently estimates the total remaining commitment to be approximately $137.5 million as of December 31, 2024, net to Kosmos, which will be funded annually by Kosmos over an estimated 12 year period. Performance Obligations As of December 31, 2024 and 2023, the Company had performance bonds and supplemental bonds totaling $169.4 million and $194.1 million, respectively, related to bonding requirements stipulated by the BOEM and other third parties for anticipated plugging and abandonment costs of certain wells and the removal of certain facilities in our Gulf of America fields.

Additional Financial Informatio

Additional Financial Information	12 Months Ended
	Dec. 31, 2024
Additional Financial Information
Additional Financial Information	Additional Financial Information Accrued Liabilities Accrued liabilities consisted of the following: December 31, 2024 2023 (In thousands) Accrued liabilities: Exploration, development and production $ 78,163 $ 90,054 Revenue payable 18,909 20,506 Current asset retirement obligations 125 2,808 General and administrative expenses 39,071 29,766 Interest 47,228 36,410 Income taxes 52,262 111,212 Taxes other than income 1,222 1,029 Derivatives 844 1,372 Other 7,130 9,658 $ 244,954 $ 302,815 Other Expenses, net Other expenses, net incurred during the period is comprised of the following: Years Ended December 31, 2024 2023 2022 (In thousands) Loss on disposal of inventory $ 1,835 $ 7,372 $ 1,521 Gain on insurance settlements — — (7,000) (Gain) loss on asset retirement obligations liability settlements (3,169) 6,034 (3,278) Other, net 19,037 10,250 (297) Other expenses, net $ 17,703 $ 23,656 $ (9,054)

Business Segment Information

Business Segment Information	12 Months Ended
	Dec. 31, 2024
Segment Reporting [Abstract]
Business Segment Information	Business Segment Information Kosmos is engaged in a single line of business, which is the exploration, development and production of oil and gas. At December 31, 2024, the Company had operations in four geographic reporting segments: Ghana, Equatorial Guinea, Mauritania/Senegal and the Gulf of America. The Company’s Chief Operating Decision Maker (“CODM”) is the Chief Executive Officer, who makes decisions about allocating resources and assessing performance for the entire company. To assess performance of the reporting segments, the CODM regularly reviews oil and gas revenues, oil and gas production costs, exploration expenses and capital expenditures by reporting segment in deciding how to allocate resources and in assessing performance. Capital expenditures, as defined by the Company, may not be comparable to similarly titled measures used by other companies and should be considered in conjunction with our consolidated financial statements and notes thereto. Financial information for each reporting segment is presented below: Ghana Equatorial Guinea Mauritania / Senegal Gulf of America Corporate & Other Eliminations Total (in thousands) Years ended December 31, 2024 Revenues and other income: Oil and gas revenue $ 1,044,562 $ 260,675 $ — $ 370,121 $ — $ — $ 1,675,358 Other income, net 48 — — 2,895 171,706 (174,445) 204 Total revenues and other income 1,044,610 260,675 — 373,016 171,706 (174,445) 1,675,562 Costs and expenses: Oil and gas production 164,385 136,398 93,412 136,319 — — 530,514 Exploration expenses 3,572 73,009 16,973 21,447 4,906 — 119,907 General and administrative 13,718 6,129 10,974 19,326 212,354 (162,346) 100,155 Depletion, depreciation and amortization 203,501 65,178 950 185,068 2,077 — 456,774 Interest and other financing costs, net(1) 51,302 (2,697) (146,952) (12,607) 199,552 — 88,598 Derivatives, net — — — — 12,099 — 12,099 Other expenses, net 14,894 (4,673) 14,764 4,782 35 (12,099) 17,703 Total costs and expenses 451,372 273,344 (9,879) 354,335 431,023 (174,445) 1,325,750 Income before income taxes 593,238 (12,669) 9,879 18,681 (259,317) — 349,812 Income tax expense 201,006 (41,217) — 14,179 (14,007) — 159,961 Net income (loss) $ 392,232 $ 28,548 $ 9,879 $ 4,502 $ (245,310) $ — $ 189,851 Consolidated capital expenditures $ 139,130 $ 177,196 $ 324,798 $ 181,160 $ 6,529 $ — $ 828,813 As of December 31, 2024 Property and equipment, net $ 986,693 $ 482,223 $ 2,057,786 $ 901,012 $ 16,507 $ — $ 4,444,221 Total assets $ 3,682,493 $ 2,313,856 $ 3,188,067 $ 4,094,116 $ 25,867,010 $ (33,836,554) $ 5,308,988 ______________________________________ (1) Interest expense is recorded based on actual third-party and intercompany debt agreements. Capitalized interest is recorded on the business unit where the assets reside. Ghana Equatorial Guinea Mauritania / Senegal Gulf of America Corporate & Other Eliminations Total (in thousands) Year ended December 31, 2023 Revenues and other income: Oil and gas revenue $ 1,062,482 $ 267,494 $ — $ 371,632 $ — $ — $ 1,701,608 Other income, net (403) 10 — 3,327 157,770 (160,777) (73) Total revenues and other income 1,062,079 267,504 — 374,959 157,770 (160,777) 1,701,535 Costs and expenses: Oil and gas production 175,265 114,411 — 100,421 — — 390,097 Exploration expenses 872 7,915 15,784 11,950 5,757 — 42,278 General and administrative 12,913 5,555 9,354 22,076 199,283 (149,649) 99,532 Depletion, depreciation and amortization 240,998 51,750 917 149,482 1,780 — 444,927 Impairment of long-lived assets 222,278 — — — — 222,278 Interest and other financing costs, net(1) 56,988 (2,942) (119,697) 6,236 155,319 — 95,904 Derivatives, net — — — — 11,128 — 11,128 Other expenses, net 7,963 3,208 7,997 10,506 5,110 (11,128) 23,656 Total costs and expenses 717,277 179,897 (85,645) 300,671 378,377 (160,777) 1,329,800 Income (loss) before income taxes 344,802 87,607 85,645 74,288 (220,607) — 371,735 Income tax expense (benefit) 122,704 35,666 — 13,643 (13,798) — 158,215 Net income (loss) $ 222,098 $ 51,941 $ 85,645 $ 60,645 $ (206,809) $ — $ 213,520 Consolidated capital expenditures $ 276,849 $ 74,573 $ 276,484 $ 212,431 $ 9,662 $ — $ 849,999 As of December 31, 2023 Property and equipment, net $ 1,036,651 $ 424,030 $ 1,788,214 $ 893,293 $ 18,041 $ — $ 4,160,229 Total assets $ 3,252,235 $ 1,918,131 $ 2,642,098 $ 3,988,805 $ 21,599,662 $ (28,462,797) $ 4,938,134 ______________________________________ (1) Interest expense is recorded based on actual third-party and intercompany debt agreements. Capitalized interest is recorded on the business unit where the assets reside. Ghana (2) Equatorial Guinea Mauritania / Senegal Gulf of America (3) Corporate & Other Eliminations Total (in thousands) Year ended December 31, 2022 Revenues and other income: Oil and gas revenue $ 1,350,962 $ 346,783 $ — $ 547,610 $ — $ — $ 2,245,355 Gain on sale of assets — — — 471 50,000 — 50,471 Other income, net 428 3,350 — 2,405 386,002 (388,236) 3,949 Total revenues and other income 1,351,390 350,133 — 550,486 436,002 (388,236) 2,299,775 Costs and expenses: Oil and gas production 212,729 90,602 — 105,968 — — 409,299 Exploration expenses 14,987 7,378 82,526 22,763 6,576 — 134,230 General and administrative 15,310 6,703 9,798 15,794 180,594 (127,343) 100,856 Depletion, depreciation and amortization 289,058 53,765 412 153,407 1,614 — 498,256 Impairment of long-lived assets 450,357 — — (388) — — 449,969 Interest and other financing costs, net(1) 64,620 (2,494) (69,644) 11,180 114,598 — 118,260 Derivatives, net — — — — 260,892 — 260,892 Other expenses, net 233,785 8,397 (1,178) 10,339 496 (260,893) (9,054) Total costs and expenses 1,280,846 164,351 21,914 319,063 564,770 (388,236) 1,962,708 Income (loss) before income taxes 70,544 185,782 (21,914) 231,423 (128,768) — 337,067 Income tax expense (benefit) 28,091 72,814 — (1,010) 10,621 — 110,516 Net income (loss) $ 42,453 $ 112,968 $ (21,914) $ 232,433 $ (139,389) $ — $ 226,551 Consolidated capital expenditures $ 98,540 $ 36,036 $ 407,982 $ 111,016 $ (41,986) $ — $ 611,588 As of December 31, 2022 Property and equipment, net $ 1,202,937 $ 396,737 $ 1,396,884 $ 829,242 $ 16,847 $ — $ 3,842,647 Total assets $ 2,886,242 $ 1,463,211 $ 2,026,776 $ 3,695,641 $ 19,554,236 $ (25,046,118) $ 4,579,988 ______________________________________ (1) Interest expense is recorded based on actual third-party and intercompany debt agreements. Capitalized interest is recorded on the business unit where the assets reside. (2) Includes activity related to the interest pre-empted by Tullow prior to the March 17, 2022 closing date of the Tullow pre-emption transaction. Additionally, cash consideration of $118.2 million is included as a reduction in Consolidated capital expenditures for the year ended December 31, 2022. (3) Includes activity related to our acquisition of an additional interest in the Kodiak oil field commencing June 9, 2022, the acquisition date. Additionally, cash consideration paid of $29.0 million is included in the Consolidated capital expenditures for the year ended December 31, 2022. Years Ended December 31, 2024 2023 2022 (In thousands) Consolidated capital expenditures: Consolidated Statements of Cash Flows - Investing activities: Oil and gas assets $ 933,659 $ 932,603 $ 787,297 Acquisition of oil and gas properties — — 22,078 Proceeds on sale of assets — — (168,703) Adjustments: Changes in capital accruals 13,392 6,732 396 Exploration expense, excluding unsuccessful well costs and leasehold impairments(1) 45,418 40,070 47,289 Capitalized interest (168,715) (138,738) (84,343) Other 5,059 9,332 7,574 Total consolidated capital expenditures $ 828,813 $ 849,999 $ 611,588 ______________________________________ (1) Unsuccessful well costs are included in oil and gas assets when incurred.

Condensed Parent Company Financ

Condensed Parent Company Financial Statements	12 Months Ended
	Dec. 31, 2024
Condensed Financial Information Disclosure [Abstract]
Schedule I - Condensed Parent Company Financial Statements	Schedule I—Condensed Parent Company Financial Statements Under the terms of agreements governing the indebtedness of subsidiaries of Kosmos Energy Ltd. for 2024, 2023 and 2022 (collectively “KEL,” the “Parent Company”), such subsidiaries may be restricted from making dividend payments, loans or advances to KEL. Schedule I of Article 5‑04 of Regulation S‑X requires the condensed financial information of the Parent Company to be filed when the restricted net assets of consolidated subsidiaries exceed 25 percent of consolidated net assets as of the end of the most recently completed fiscal year. The following condensed parent‑only financial statements of KEL have been prepared in accordance with Rule 12‑04, Schedule I of Regulation S‑X and included herein. The Parent Company’s 100% investment in its subsidiaries has been recorded using the equity basis of accounting in the accompanying condensed parent‑only financial statements. The condensed financial statements should be read in conjunction with the consolidated financial statements of Kosmos Energy Ltd. and subsidiaries and notes thereto. The terms “Kosmos,” the “Company,” and similar terms refer to Kosmos Energy Ltd. and its wholly-owned subsidiaries, unless the context indicates otherwise. Certain prior period amounts have been reclassified to conform with the current year presentation. Such reclassifications had no impact on our reported net income, current assets, total assets, current liabilities, total liabilities or shareholders equity. KOSMOS ENERGY LTD. CONDENSED PARENT COMPANY BALANCE SHEETS (In thousands, except share data) December 31, 2024 2023 Assets Current assets: Cash and cash equivalents $ 39 $ 275 Prepaid expenses and other 707 752 Total current assets 746 1,027 Investment in subsidiaries at equity 3,262,312 2,683,656 Deferred financing costs, net of accumulated amortization of $11,668 and $15,583 at December 31, 2024 and December 31, 2023, respectively — 2,320 Restricted cash 305 305 Long-term deferred tax asset 22,919 12,050 Total assets $ 3,286,282 $ 2,699,358 Liabilities and shareholders’ equity Current liabilities: Accounts payable $ 23 $ 12 Accounts payable to subsidiaries 175,922 152,679 Accrued liabilities 34,845 27,650 Total current liabilities 210,790 180,341 Long-term debt, net 1,875,068 1,486,680 Shareholders’ equity: Preference shares, $0.01 par value; 200,000,000 authorized shares; zero issued at December 31, 2024 and December 31, 2023 — — Common stock, $0.01 par value; 2,000,000,000 authorized shares; 516,158,749 and 504,392,980 issued at December 31, 2024 and December 31, 2023, respectively 5,162 5,044 Additional paid-in capital 2,514,739 2,536,621 Accumulated deficit (1,082,470) (1,272,321) Treasury stock, at cost, 44,263,269 shares at December 31, 2024 and 2023, respectively (237,007) (237,007) Total shareholders’ equity 1,200,424 1,032,337 Total liabilities and shareholders’ equity $ 3,286,282 $ 2,699,358 CONDENSED PARENT COMPANY STATEMENTS OF OPERATIONS (In thousands) Years Ended December 31, 2024 2023 2022 Revenues and other income: Oil and gas revenue $ — $ — $ — Other income—related party — — 75,740 Total revenues and other income — — 75,740 Costs and expenses: General and administrative 49,279 52,279 44,180 General and administrative recoveries—related party 1,326 (6,048) (3,772) Interest and other financing costs, net 136,950 122,773 123,247 Derivatives, net — — 75,740 Other expenses, net 65 131 17 Equity in (earnings) of subsidiaries (365,362) (370,729) (415,546) Total costs and expenses (177,742) (201,594) (176,134) Income before income taxes 177,742 201,594 251,874 Income tax expense (benefit) (12,109) (11,926) 25,323 Net income $ 189,851 $ 213,520 $ 226,551 CONDENSED PARENT COMPANY STATEMENTS OF CASH FLOWS (In thousands) Years Ended December 31, 2024 2023 2022 Operating activities Net income $ 189,851 $ 213,520 $ 226,551 Adjustments to reconcile net income to net cash (used in) operating activities: Equity in (earnings) of subsidiaries (365,362) (370,729) (415,546) Equity-based compensation 37,951 42,693 34,546 Depreciation and amortization 7,497 6,588 6,359 Deferred income taxes (10,869) (11,589) 18,034 Other income—related party — 413 (4,353) Change in fair value of derivatives — — 75,741 Cash settlements on derivatives — — (70,327) Debt modifications and extinguishments 3,192 — 192 Changes in assets and liabilities: Decrease in receivables 6 87 306 (Increase) decrease in prepaid expenses and other 45 299 (94) Decrease due to/from related party 22,501 37,765 33,214 Increase (decrease) in accounts payable and accrued liabilities 6,694 60 (4,159) Net cash (used in) operating activities (108,494) (80,893) (99,536) Investing activities Investment in subsidiaries (213,294) 90,858 104,676 Net cash provided by (used in) investing activities (213,294) 90,858 104,676 Financing activities Net proceeds from issuance of senior notes 885,285 — — Repurchase of senior notes (499,515) — — Purchase of capped call transactions (49,800) Dividends — (166) (655) Other financing costs (14,418) (11,810) (8,892) Net cash provided by (used in) financing activities 321,552 (11,976) (9,547) Net (decrease) in cash and cash equivalents (236) (2,011) (4,407) Cash, cash equivalents and restricted cash at beginning of period 580 2,591 6,998 Cash, cash equivalents and restricted cash at end of period $ 344 $ 580 $ 2,591

Valuation and Qualifying Accoun

Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2024
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
Valuation and Qualifying Accounts	Valuation and Qualifying Accounts For the Years Ended December 31, 2024, 2023 and 2022 Additions Description Balance January 1, Charged to Costs and Expenses Charged To Other Accounts Deductions From Reserves Balance December 31, 2024 Allowance for credit losses $ 9,847 $ 3,721 $ — $ — $ 13,568 Allowance for deferred tax assets $ 333,651 $ 72,180 $ — $ — $ 405,831 2023 Allowance for credit losses $ 7,011 $ 2,842 $ (6) $ — $ 9,847 Allowance for deferred tax assets $ 312,727 $ 20,924 $ — $ — $ 333,651 2022 Allowance for credit losses $ 5,189 $ 2,509 $ (687) $ — $ 7,011 Allowance for deferred tax assets $ 318,343 $ (5,616) $ — $ — $ 312,727 Schedules other than Schedule I and Schedule II have been omitted because they are not applicable or the required information is presented in the consolidated financial statements or the notes to consolidated financial statements.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pay vs Performance Disclosure
Net income	$ 189,851	$ 213,520	$ 226,551

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Dec. 31, 2024
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

Insider Trading Policies and Pr

Insider Trading Policies and Procedures	12 Months Ended
	Dec. 31, 2024
Insider Trading Policies and Procedures [Line Items]
Insider Trading Policies and Procedures Adopted	true

Cybersecurity Risk Management a

Cybersecurity Risk Management and Strategy Disclosure	12 Months Ended
	Dec. 31, 2024
Cybersecurity Risk Management, Strategy, and Governance [Line Items]
Cybersecurity Risk Management Processes for Assessing, Identifying, and Managing Threats [Text Block]	At Kosmos Energy, cybersecurity risk management is an integral part of our overall Information Technology Disaster Recovery and Security Incident Response Plan. Our cybersecurity risk management program is designed to align with our business strategy based on the size of our company and the level of complexity of our information technology systems and industry best practices. The framework for handling cybersecurity threats and incidents including threats and incidents associated with the use of applications developed and services provided by third-party service providers and coordination across different departments of our company includes assessing the severity of a cybersecurity threat associated with a third-party service provider, various cybersecurity countermeasures and mitigation strategies and informing management and the Audit Committee to our board of directors of material cybersecurity threats and incidents. Our information technology team is responsible for assessing our cybersecurity risk management program and we currently do not engage third parties for such design of our cybersecurity risk management program. In addition, our information technology team provides cybersecurity training to all employees and contractors annually.
Cybersecurity Risk Management Processes Integrated [Flag]	true
Cybersecurity Risk Management Processes Integrated [Text Block]	At Kosmos Energy, cybersecurity risk management is an integral part of our overall Information Technology Disaster Recovery and Security Incident Response Plan. Our cybersecurity risk management program is designed to align with our business strategy based on the size of our company and the level of complexity of our information technology systems and industry best practices. The framework for handling cybersecurity threats and incidents including threats and incidents associated with the use of applications developed and services provided by third-party service providers and coordination across different departments of our company includes assessing the severity of a cybersecurity threat associated with a third-party service provider, various cybersecurity countermeasures and mitigation strategies and informing management and the Audit Committee to our board of directors of material cybersecurity threats and incidents. Our information technology team is responsible for assessing our cybersecurity risk management program and we currently do not engage third parties for such design of our cybersecurity risk management program. In addition, our information technology team provides cybersecurity training to all employees and contractors annually.
Cybersecurity Risk Management Third Party Engaged [Flag]	false
Cybersecurity Risk Third Party Oversight and Identification Processes [Flag]	true
Cybersecurity Risk Materially Affected or Reasonably Likely to Materially Affect Registrant [Flag]	false
Cybersecurity Risk Board of Directors Oversight [Text Block]	The Audit Committee to our board of directors has overall oversight responsibility for our risk management, and is charged with oversight of our cybersecurity risk management program. The Audit Committee is responsible for ensuring that management has processes in place designed to identify and evaluate cybersecurity risks to which the company is exposed and implement processes and programs to manage cybersecurity risks and mitigate cybersecurity incidents. The Audit Committee also reports material cybersecurity risks to our full board of directors. Management is responsible for identifying and assessing material cybersecurity risks on an ongoing basis, establishing processes to ensure that such potential cybersecurity risk exposures are monitored, putting in place appropriate mitigation measures and maintaining cybersecurity programs. Our cybersecurity programs are under the direction of our Chief Information Officer (CIO) who receives reports from our information technology team and monitors the prevention, detection, mitigation, and remediation of cybersecurity incidents. Our CIO and dedicated personnel are certified and experienced information systems security professionals and information security managers with many years of experience. Management, including the CIO, and our information technology team, regularly update the Audit Committee on the Company’s cybersecurity programs, material cybersecurity risks and mitigation strategies and provide cybersecurity reports quarterly that cover, among other topics, results of third-party testing and assessments of the Company’s cybersecurity programs, developments in cybersecurity and updates to the Company’s cybersecurity programs and mitigation strategies. In 2024, we did not identify any cybersecurity threats that have materially affected or are reasonably likely to materially affect our business strategy, results of operations, or financial condition. However, despite our efforts, we cannot eliminate all risks from cybersecurity threats, or provide assurances that we have not experienced an undetected cybersecurity incident. For more information about these risks, please see “Risk Factors” in this annual report on Form 10-K.
Cybersecurity Risk Board Committee or Subcommittee Responsible for Oversight [Text Block]	The Audit Committee to our board of directors has overall oversight responsibility for our risk management, and is charged with oversight of our cybersecurity risk management program. The Audit Committee is responsible for ensuring that management has processes in place designed to identify and evaluate cybersecurity risks to which the company is exposed and implement processes and programs to manage cybersecurity risks and mitigate cybersecurity incidents. The Audit Committee also reports material cybersecurity risks to our full board of directors. Management is responsible for identifying and assessing material cybersecurity risks on an ongoing basis, establishing processes to ensure that such potential cybersecurity risk exposures are monitored, putting in place appropriate mitigation measures and maintaining cybersecurity programs. Our cybersecurity programs are under the direction of our Chief Information Officer (CIO) who receives reports from our information technology team and monitors the prevention, detection, mitigation, and remediation of cybersecurity incidents. Our CIO and dedicated personnel are certified and experienced information systems security professionals and information security managers with many years of experience.
Cybersecurity Risk Process for Informing Board Committee or Subcommittee Responsible for Oversight [Text Block]	The Audit Committee
Cybersecurity Risk Role of Management [Text Block]	The Audit Committee also reports material cybersecurity risks to our full board of directors. Management is responsible for identifying and assessing material cybersecurity risks on an ongoing basis, establishing processes to ensure that such potential cybersecurity risk exposures are monitored, putting in place appropriate mitigation measures and maintaining cybersecurity programs. Our cybersecurity programs are under the direction of our Chief Information Officer (CIO) who receives reports from our information technology team and monitors the prevention, detection, mitigation, and remediation of cybersecurity incidents. Our CIO and dedicated personnel are certified and experienced information systems security professionals and information security managers with many years of experience. Management, including the CIO, and our information technology team, regularly update the Audit Committee on the Company’s cybersecurity programs, material cybersecurity risks and mitigation strategies and provide cybersecurity reports quarterly that cover, among other topics, results of third-party testing and assessments of the Company’s cybersecurity programs, developments in cybersecurity and updates to the Company’s cybersecurity programs and mitigation strategies.
Cybersecurity Risk Management Positions or Committees Responsible [Flag]	true
Cybersecurity Risk Management Positions or Committees Responsible [Text Block]	Our cybersecurity programs are under the direction of our Chief Information Officer (CIO) who receives reports from our information technology team and monitors the prevention, detection, mitigation, and remediation of cybersecurity incidents. Our CIO and dedicated personnel are certified and experienced information systems security professionals and information security managers with many years of experience. Management, including the CIO, and our information technology team, regularly update the Audit Committee on the Company’s cybersecurity programs, material cybersecurity risks and mitigation strategies and provide cybersecurity reports quarterly that cover, among other topics, results of third-party testing and assessments of the Company’s cybersecurity programs, developments in cybersecurity and updates to the Company’s cybersecurity programs and mitigation strategies.
Cybersecurity Risk Management Expertise of Management Responsible [Text Block]	Our cybersecurity programs are under the direction of our Chief Information Officer (CIO) who receives reports from our information technology team and monitors the prevention, detection, mitigation, and remediation of cybersecurity incidents. Our CIO and dedicated personnel are certified and experienced information systems security professionals and information security managers with many years of experience
Cybersecurity Risk Process for Informing Management or Committees Responsible [Text Block]	Our cybersecurity programs are under the direction of our Chief Information Officer (CIO) who receives reports from our information technology team and monitors the prevention, detection, mitigation, and remediation of cybersecurity incidents. Our CIO and dedicated personnel are certified and experienced information systems security professionals and information security managers with many years of experience. Management, including the CIO, and our information technology team, regularly update the Audit Committee on the Company’s cybersecurity programs, material cybersecurity risks and mitigation strategies and provide cybersecurity reports quarterly that cover, among other topics, results of third-party testing and assessments of the Company’s cybersecurity programs, developments in cybersecurity and updates to the Company’s cybersecurity programs and mitigation strategies.
Cybersecurity Risk Management Positions or Committees Responsible Report to Board [Flag]	true

Accounting Policies (Policies)

Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2024
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation The accompanying consolidated financial statements include the accounts of Kosmos Energy Ltd. and its wholly-owned subsidiaries. They also include the Company’s share of the undivided interest in certain assets, liabilities, revenues and expenses.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosures of contingent assets and liabilities. These estimates could change materially if different information or assumptions were used. We base our assumptions and estimates on historical experience and other sources that we believe to be reasonable at the time. Actual results could differ from these estimates.
Reclassifications	Reclassifications Certain prior period amounts have been reclassified to conform with the current year presentation. Such reclassifications had no significant impact on our reported net income, current assets, total assets, current liabilities, total liabilities, shareholders’ equity or cash flows.
Cash, Cash Equivalents and Restricted Cash	Cash, Cash Equivalents and Restricted Cash Cash and cash equivalents includes demand deposits and funds invested in highly liquid instruments with original maturities of three months or less at the date of purchase. When our net leverage ratio exceeds 2.50x, we are required under the Facility to maintain a restricted cash balance that is sufficient to meet the payment of interest and fees for the next six-month period on the 7.125% Senior Notes, the 7.750% Senior Notes, the 7.500% Senior Notes, the 8.750% Senior Notes and the 3.125% Convertible Senior Notes or the Facility, whichever is greater. As of December 31, 2024, our net leverage ratio was 2.54x, partially due to pre-production operating costs associated with the GTA Phase 1 project. Our next financial covenant assessment date is March 31, 2025, after which date we could be required to restrict approximately $66.0 million in cash as required under the terms of the Facility unless otherwise waived by the lenders. As of December 31, 2023 our net leverage ratio was below 2.50x.
Receivables	Receivables
Inventories	The Company’s materials and supplies inventory primarily consists of casing and wellheads and is stated at the lower of cost, using the weighted average cost method, or net realizable value. We recorded write downs of $1.8 million, $7.4 million and $1.5 million during the years ended December 31, 2024, 2023 and 2022 for materials and supplies inventories as Other expenses, net in the consolidated statements of operations and other in the consolidated statements of cash flows. Hydrocarbon inventory is carried at the lower of cost, using the weighted average cost method, or net realizable value. Hydrocarbon inventory costs include expenditures and other charges incurred in bringing the inventory to its existing condition. Selling expenses and general and administrative expenses are reported as period costs and excluded from inventory costs.
Exploration and Development Costs	Exploration and Development Costs The Company follows the successful efforts method of accounting for its oil and gas properties. Acquisition costs for proved and unproved properties are capitalized when incurred. Costs of unproved properties are transferred to proved properties when a determination that proved reserves have been found. Exploration costs, including geological and geophysical costs and costs of carrying unproved properties, are expensed as incurred. Exploratory drilling costs are capitalized when incurred. If exploratory wells are determined to be commercially unsuccessful or dry holes, the applicable costs are expensed and recorded in exploration expense on the consolidated statement of operations. Costs incurred to drill and equip development wells, including unsuccessful development wells, are capitalized. Costs incurred to operate and maintain wells and equipment and to lift oil and natural gas to the surface are expensed as oil and gas production expense. The Company evaluates unproved property periodically for impairment. The impairment assessment considers results of exploration activities, commodity price outlooks, planned future sales or expiration of all or a portion of such projects. If it is determined that future appraisal drilling or development activities are unlikely to occur, the associated capitalized costs are recorded as exploration expense in the consolidated statement of operations.
Depletion, Depreciation and Amortization	Depletion, Depreciation and Amortization Proved properties and support equipment and facilities are depleted using the unit‑of‑production method based on estimated proved oil and gas reserves. Capitalized exploratory drilling costs that result in a discovery of proved reserves and development costs are depleted using the unit‑of‑production method based on estimated proved developed oil and gas reserves for the related field. Amortization of deferred financing costs is computed using the straight‑line method over the life of the related debt.
Capitalized Interest	Capitalized Interest Interest costs from external borrowings are capitalized on major projects with an expected construction period of one year or longer. Capitalized interest is added to the cost of the underlying asset and is depleted on the unit‑of‑production method in the same manner as the underlying assets.
Asset Retirement Obligations	Asset Retirement Obligations The Company accounts for asset retirement obligations as required by ASC 410—Asset Retirement and Environmental Obligations. Under these standards, the fair value of a liability for an asset retirement obligation is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. If a reasonable estimate of fair value cannot be made in the period the asset retirement obligation is incurred, the liability is recognized when a reasonable estimate of fair value can be made. If a tangible long‑lived asset with an existing asset retirement obligation is acquired, a liability for that obligation is recognized at the asset’s acquisition or in service date. In addition, a liability for the fair value of a conditional asset retirement obligation is recorded if the fair value of the liability can be reasonably estimated. We capitalize the asset retirement costs by increasing the carrying amount of the related long‑lived asset by the same amount as the liability. We record increases in the discounted abandonment liability resulting from the passage of time in depletion, depreciation and amortization in the consolidated statement of operations. Estimating the future restoration and removal costs requires management to make estimates and judgments because most of the removal obligations are many years in the future and the regulations in some countries that we operate often have vague descriptions of what constitutes removal. Additionally, asset removal technologies and costs are constantly changing, as are regulatory, political, environmental, safety and public relations considerations. Inherent in the present value calculation are numerous assumptions and judgments including the ultimate settlement amounts, inflation factors, credit adjusted discount rates, timing of settlement and changes in the legal, regulatory, environmental and political environments. To the extent future revisions to these assumptions impact the present value of the existing asset retirement obligations, a corresponding adjustment is made to the oil and gas property balance.
Acquisition Accounting	Acquisition Accounting The purchase price in an acquisition (business combination or asset acquisition) is allocated to the assets acquired and liabilities assumed based on their relative fair values as of the acquisition date, which may occur many months after the deal announcement date. Therefore, while the consideration to be paid may be fixed, the fair value of the assets acquired, and liabilities assumed is subject to change during the period between the announcement date and the acquisition date. The most significant estimates in the allocation typically relate to the value assigned to future recoverable oil and gas reserves and unproved properties. As the allocation of the purchase price is subject to significant estimates and subjective judgments, the accuracy of this assessment is inherently uncertain.
Impairment of Long-lived Assets	Impairment of Long‑lived Assets We review our long‑lived assets for impairment when changes in circumstances indicate that the carrying amount of an asset may not be recoverable. ASC 360 — Property, Plant and Equipment requires an impairment loss to be recognized if the carrying amount of a long‑lived asset is not recoverable and exceeds its fair value. The carrying amount of a long‑lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. That assessment shall be based on the carrying amount of the asset at the date it is tested for recoverability, whether in use or under development. Assets to be disposed of and assets not expected to provide any future service potential to us are recorded at the lower of carrying amount or fair value. Oil and gas properties are grouped in accordance with ASC 932 — Extractive Activities-Oil and Gas. The basis for grouping is a reasonable aggregation of properties typically by field or by logical grouping of assets with significant shared infrastructure. For long-lived assets whereby the carrying value exceeds the estimated future undiscounted cash flows, the carrying amount is reduced to fair value. Fair value is generally estimated using the income approach described in the ASC 820 — Fair Value Measurement. If applicable, we utilize prices and other relevant information generated by market transactions involving assets and liabilities that are identical or comparable to the item being measured as the basis for determining fair value. The expected future cash flows used for impairment reviews and related fair value measurements are typically based on judgmental assessments of future production, pricing estimates, capital and operating costs, market-based weighted average cost of capital, and risk adjustment factors applied to reserves. These assumptions are applied to develop future cash flow projections that are then discounted to estimated fair value, using a market-based weighted-average cost of capital.
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities
Estimates of Proved Oil and Gas Reserves	Estimates of Proved Oil and Gas Reserves Reserve quantities and the related estimates of future net cash flows affect our periodic calculations of depletion and assessment of impairment of our oil and natural gas properties. Proved oil and gas reserves are the estimated quantities of crude oil, natural gas and natural gas liquids that geological and engineering data demonstrate with reasonable certainty to be recoverable in future periods from known reservoirs under existing economic and operating conditions. Proved reserve quantities and future cash flows are estimated by independent petroleum engineering consultants and prepared in accordance with guidelines established by the SEC and the FASB. The accuracy of these reserve estimates is a function of: • the engineering and geological interpretation of available data; • estimates of the amount and timing of future operating cost, production taxes, development cost and workover cost; • the accuracy of various mandated economic assumptions; and • the judgments of the persons preparing the estimates.
Revenue Recognition	Revenue Recognition We recognize revenues on the volumes of hydrocarbons sold to a purchaser. The volumes sold may be more or less than the volumes to which we are entitled based on our ownership interest in the property. These differences result in a condition known in the industry as a production imbalance. A receivable or liability is recognized only to the extent that we have an imbalance on a specific property greater than the expected remaining proved reserves on such property. As of December 31, 2024 and 2023, we had no oil and gas imbalances recorded in our consolidated financial statements. Our oil and gas revenues are recognized when hydrocarbons have been sold to a purchaser at a fixed or determinable price, title has transferred and collection is probable. Certain revenues are based on contracts with provisional pricing and quantity optionality which contain a derivative that is separated from the host contract for accounting purposes. The host contract is the receivable from oil sales at the spot price on the date of sale. The derivative, which is not designated as a hedge, is marked to market through oil and gas revenue each period until the final settlement occurs, which generally is limited to the month of or month after the sale.
Equity-based Compensation	Equity‑based Compensation For equity‑based compensation awards, compensation expense is recognized in the Company’s financial statements over the awards’ vesting periods based on their grant date fair value. The Company utilizes (i) the closing stock price on the date of grant to determine the fair value of service vesting restricted stock units and (ii) a Monte Carlo simulation to determine the fair value of restricted stock units with a combination of market and service vesting criteria. Forfeitures are recognized in the period in which they occur.
Income Taxes	Income Taxes The Company accounts for income taxes as required by ASC 740—Income Taxes. Under this method, deferred income taxes are determined based on the difference between the financial statement and tax basis of assets and liabilities using enacted tax rates in effect for the year in which the differences are expected to reverse. Valuation allowances are established when necessary to reduce deferred tax assets to the amounts expected to be realized. On a quarterly basis, management evaluates the need for and adequacy of valuation allowances based on the expected realizability of the deferred tax assets and adjusts the amount of such allowances, if necessary. We recognize tax benefits from uncertain tax positions only if it is more likely than not that the tax position will be sustained upon examination by the tax authorities, based on the technical merits of the position. Accordingly, we measure tax benefits from such positions based on the most likely outcome to be realized.
Foreign Currency Translation	Foreign Currency Translation The U.S. dollar is the functional currency for all of the Company’s material foreign operations. Foreign currency transaction gains and losses and adjustments resulting from translating monetary assets and liabilities denominated in foreign currencies are included in other expenses. Cash balances held in foreign currencies are not significant, and as such, the effect of exchange rate changes is not material to any reporting period.
Concentration of Credit Risk	Concentration of Credit Risk Our revenue can be materially affected by current economic conditions and the price of oil and natural gas. However, based on the current demand for crude oil and natural gas and the fact that alternative purchasers are readily available, we believe that the loss of our marketing agents and/or any of the purchasers identified by our marketing agents would not have a long‑term material adverse effect on our financial position or results of international operations. The economic disruption resulting from Russia’s continued war in Ukraine, ongoing instability in the Middle East, a potential global recession, inflationary pressures and other varying macroeconomic conditions could materially impact the Company's business in future periods. Any potential disruption will depend on the duration and intensity of these events, which are highly uncertain and cannot be predicted at this time.
Recent Accounting Standards	Recent Accounting Standards Recently Adopted In November 2023, the FASB issued “ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The amendment requires disclosures of significant segment expenses that are regularly provided to the chief operating decision maker (“CODM”) and included within each reported measure of segment profit or loss, an amount and description of its composition for other segment items, and interim disclosures of a reportable segment’s profit of loss and assets. The amendments are effective for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Not Yet Adopted
Fair Value Measurements	In accordance with ASC 820—Fair Value Measurements, fair value measurements are based upon inputs that market participants use in pricing an asset or liability, which are classified into two categories: observable inputs and unobservable inputs. Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company’s own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. We prioritize the inputs used in measuring fair value into the following fair value hierarchy: • Level 1 — quoted prices for identical assets or liabilities in active markets. • Level 2 — quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs derived principally from or corroborated by observable market data by correlation or other means. • Level 3 — unobservable inputs for the asset or liability. The fair value input hierarchy level to which an asset or liability measurement in its entirety falls is determined based on the lowest level input that is significant to the measurement in its entirety.

Accounting Policies (Tables)

Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2024
Accounting Policies [Abstract]
Schedule of Cash and Cash Equivalents	December 31, 2024 2023 2022 (In thousands) Cash and cash equivalents $ 84,972 $ 95,345 $ 183,405 Restricted cash - long-term 305 3,416 3,416 Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 85,277 $ 98,761 $ 186,821
Schedule of Estimated Useful Lives of Other Property	Depreciation and amortization of other property is computed using the straight-line method over the assets’ estimated useful lives (not to exceed the lease term for leasehold improvements), ranging from one Years Leasehold improvements 1 to 8 Office furniture, fixtures and computer equipment 3 to 7
Schedule of Oil and Gas Revenue	Oil and gas revenue is composed of the following: Years Ended December 31, 2024 2023 2022 (In thousands) Revenues from contracts with customers: Equatorial Guinea $ 257,961 $ 273,280 $ 349,443 Ghana 1,052,126 1,073,917 1,362,875 Gulf of America 370,121 371,632 547,610 Total revenues from contracts with customers 1,680,208 1,718,829 2,259,928 Provisional oil sales contracts (4,850) (17,221) (14,573) Oil and gas revenue $ 1,675,358 $ 1,701,608 $ 2,245,355

Receivables (Tables)

Receivables (Tables)	12 Months Ended
	Dec. 31, 2024
Receivables [Abstract]
Schedule of Receivables	Receivables consisted of the following: December 31, 2024 2023 (In thousands) Joint interest billings, net 33,120 35,632 Oil sales 89,694 64,958 Other current receivables 42,145 20,143 Total receivables 164,959 120,733 Long-term receivables 385,463 325,181

Property and Equipment (Tables)

Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2024
Property, Plant and Equipment [Abstract]
Schedule of Property and Equipment	Property and equipment is stated at cost and consisted of the following: December 31, 2024 2023 (In thousands) Oil and gas properties: Proved properties $ 8,342,353 $ 7,600,252 Unproved properties 386,292 423,050 Total oil and gas properties 8,728,645 8,023,302 Accumulated depletion (4,288,215) (3,868,946) Oil and gas properties, net 4,440,430 4,154,356 Other property 66,675 65,095 Accumulated depreciation (62,884) (59,222) Other property, net 3,791 5,873 Property and equipment, net $ 4,444,221 $ 4,160,229

Suspended Well Costs (Tables)

Suspended Well Costs (Tables)	12 Months Ended
	Dec. 31, 2024
Oil and Gas Disclosure [Abstract]
Schedule of Capitalized Exploratory Well Costs	The following table reflects the Company’s capitalized exploratory well costs on drilled wells as of and during the years ended December 31, 2024, 2023 and 2022. Years Ended December 31, 2024 2023 2022 (In thousands) Beginning balance $ 211,959 $ 145,957 $ 218,180 Additions to capitalized exploratory well costs pending the determination of proved reserves 21,418 66,002 25,209 Reclassification due to determination of proved reserves(1) — — (34,614) Capitalized exploratory well costs charged to expense(2) (37,175) — (62,818) Ending balance $ 196,202 $ 211,959 $ 145,957 ______________________________________ (1) Activity for the year ended December 31, 2022 represents the reclassification of exploratory well costs associated with the Winterfell discovery in Green Canyon Block 944 in the Gulf of America. (2) Activity for the year ended December 31, 2024 represents the impairment of exploratory well costs associated with the Asam discovery in Block S offshore Equatorial Guinea. Activity for the year ended December 31, 2022 represents the impairment of exploratory well costs associated with the BirAllah and Orca discoveries as a result of the expiration of the exploration period of Block C8 in June 2022.
Schedule of Aging of Capitalized Exploratory Well Costs and Number of Projects for which Exploratory Well Costs were Capitalized for More than One Year	The following table provides aging of capitalized exploratory well costs based on the date drilling was completed and the number of projects for which exploratory well costs have been capitalized for more than one year since the completion of drilling: Years Ended December 31, 2024 2023 2022 (In thousands, except well counts) Exploratory well costs capitalized for a period of one year or less $ — $ 54,274 $ — Exploratory well costs capitalized for a period of one to five years 63,552 34,775 75,941 Exploratory well costs capitalized for a period of six to ten years 132,650 122,910 70,016 Ending balance $ 196,202 $ 211,959 $ 145,957 Number of projects that have exploratory well costs that have been capitalized for a period greater than one year 2 2 2

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2024
Leases [Abstract]
Schedule of Components of Lease Cost	The components of lease cost for the years ended December 31, 2024, 2023 and 2022 is as follows: December 31, 2024 2023 2022 (In thousands) Operating lease cost $ 3,864 $ 3,866 $ 3,882 Variable lease cost 1,963 1,766 1,825 Short-term lease cost(1) 12,281 17,464 13,970 Total lease cost $ 18,108 $ 23,096 $ 19,677 __________________________________ (1) Includes $10.7 million, $16.0 million and $12.4 million during the years ended December 31, 2024, 2023 and 2022, respectively, of costs associated with short-term drilling contracts. The table below presents supplemental cash flow information related to leases during the years ended December 31, 2024, 2023 and 2022: December 31, 2024 2023 2022 (In thousands) Operating cash flows for operating leases $ 7,683 $ 7,256 $ 7,170 Investing cash flows for operating leases(1) 10,746 16,029 12,449 __________________________________ (1) Represents costs associated with short-term drilling contracts.
Schedule of Other Information Leases	Other information related to operating leases at December 31, 2024 and 2023, is as follows: December 31, 2024 2023 (In thousands, except lease term and discount rate) Balance sheet classifications Other assets (right-of-use assets) $ 12,294 $ 14,234 Accrued liabilities (current maturities of leases) 2,816 2,492 Other long-term liabilities (non-current maturities of leases) 12,745 15,576 Weighted average remaining lease term 4.6 years 5.6 years Weighted average discount rate 9.8 % 9.8 %
Schedule of Future Minimum Rental Commitments	Future minimum rental commitments under our leases at December 31, 2024, are as follows: Operating Leases(1) (In thousands) 2025 $ 4,189 2026 4,260 2027 4,201 2028 3,844 2029 2,808 Thereafter — Total undiscounted lease payments $ 19,302 Less: Imputed interest (3,741) Total lease liabilities $ 15,561 __________________________________ (1) Does not include purchase commitments for jointly owned fields and facilities where we are not the operator and excludes commitments for exploration activities, including well commitments, in our petroleum contracts.

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2024
Debt Disclosure [Abstract]
Schedule of Debt	December 31, 2024 2023 (In thousands) Outstanding debt principal balances: Facility $ 900,000 $ 925,000 7.125% Senior Notes 250,000 650,000 7.750% Senior Notes 350,000 400,000 7.500% Senior Notes 400,274 450,000 8.750% Senior Notes 500,000 — 3.125% Convertible Senior Notes 400,000 — Total long-term debt 2,800,274 2,425,000 Unamortized deferred financing costs and discounts(1) (55,562) (34,086) Long-term debt, net $ 2,744,712 $ 2,390,914 ________________________________________ (1) Includes $30.4 million and $20.8 million of unamortized deferred financing costs related to the Facility, $14.1 million and $13.3 million of unamortized deferred financing costs and discounts related to the Senior Notes, and $$11.1 million and nil of unamortized deferred financing costs related to the 3.125% Convertible Senior Notes as of December 31, 2024 and December 31, 2023, respectively.
Schedule of Redemption Price	On or after April 4, 2022, the Company may redeem all or a part of the 7.125% Senior Notes at the redemption prices (expressed as percentages of principal amount) set forth below plus accrued and unpaid interest: Year Percentage On or after April 4, 2022 103.563 % On or after April 4, 2023 101.781 % On or after April 4, 2024 100.000 % On or after November 1, 2023, the Company may redeem all or a part of the 7.750% Senior Notes at the redemption prices (expressed as percentages of principal amount) set forth below plus accrued and unpaid interest: Year Percentage On or after November 1, 2023 103.875 % On or after November 1, 2024 101.938 % On or after November 1, 2025 100.000 % On or after March 1, 2024, the Company may redeem all or a part of the 7.500% Senior Notes at the redemption prices (expressed as percentages of principal amount) set forth below plus accrued and unpaid interest: Year Percentage On or after March 1, 2024 103.750 % On or after March 1, 2025 101.875 % On or after March 1, 2026 100.000 % Year Percentage 2027 104.375 % 2028 102.188 % 2029 and thereafter 100.000 %
Schedule of Estimated Repayments of Debt	At December 31, 2024, the estimated repayments of debt during the five fiscal year periods and thereafter are as follows: Payments Due by Year Total 2025 2026 2027 2028 2029 Thereafter (In thousands) Principal debt repayments(1) $ 2,800,274 $ — $ 250,000 $ 350,000 $ 746,319 $ 553,955 $ 900,000 _______________________________________ (1) Includes the scheduled maturities for outstanding principal debt balances. The scheduled maturities of debt related to the Facility as of December 31, 2024 are based on our level of borrowings and our estimated future available borrowing base commitment levels in future periods. Any increases or decreases in the level of borrowings or increases or decreases in the available borrowing base would impact the scheduled maturities of debt during the next five years and thereafter.
Schedule of Interest and Other Financing Costs, Net	Interest and other financing costs, net incurred during the period comprised of the following: Years Ended December 31, 2024 2023 2022 (In thousands) Interest expense $ 214,440 $ 207,629 $ 180,046 Amortization—deferred financing costs 8,709 9,921 10,401 Debt modifications and extinguishments 25,173 1,503 192 Capitalized interest (168,715) (138,738) (84,342) Deferred interest (281) 3,183 (3,318) Interest income (24,129) (19,456) (12,139) Other, net 33,401 31,862 27,420 Interest and other financing costs, net $ 88,598 $ 95,904 $ 118,260

Derivative Financial Instrume_2

Derivative Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Oil Derivative Contracts and Interest Rate Swap	The following table sets forth the volumes in barrels underlying the Company’s outstanding oil derivative contracts and the weighted average prices per Bbl for those contracts as of December 31, 2024. Volumes and weighted average prices are net of any offsetting derivative contracts entered into. Weighted Average Price per Bbl Term Type of Contract Index MBbl Net Deferred Premium Payable/(Receivable) Swap Sold Put Floor Ceiling 2025: Jan - Jun Two-way collars Dated Brent 2,000 0.50 — — 70.00 85.00 Jan - Jun Swaps Dated Brent 2,000 — 75.48 — — — Jan - Dec Two-way collars Dated Brent 2,000 1.00 — — 70.00 85.00 ______________________________________ The following table summarized our open interest rate swaps whereby we pay a fixed rate of interest and the counterparty pays a variable SOFR-based rate as of December 31, 2024: Weighted Average Term Type of Contract Floating Rate Notional Fixed Rate (In Thousands) Jan - Dec 2025 Swap 1-Month TERM SOFR $ 500,000 3.645 %
Schedule of Derivative Instruments by Balance Sheet Location	The following tables disclose the Company’s derivative instruments as of December 31, 2024 and 2023 and gain/(loss) from derivatives during the years ended December 31, 2024, 2023 and 2022. Estimated Fair Value Asset (Liability) December 31, Type of Contract Balance Sheet Location 2024 2023 (In thousands) Derivatives not designated as hedging instruments: Derivative assets: Commodity Derivatives assets—current $ 6,714 $ 8,346 Provisional oil sales Receivables: Oil sales 2,242 — Interest rate Derivatives assets—current 2,202 — Commodity Derivatives assets—long-term 512 1,594 Derivative liabilities: Commodity Derivatives liabilities—current — (3,103) Provisional oil sales Receivables: Oil sales — (72) Total derivatives not designated as hedging instruments $ 11,670 $ 6,765
Schedule of Derivative Instruments by Location of Gain/(Loss)	Amount of Gain/(Loss) Years Ended December 31, Type of Contract Location of Gain/(Loss) 2024 2023 2022 (In thousands) Derivatives not designated as hedging instruments: Provisional oil sales Oil and gas revenue $ (4,850) $ (17,221) $ (14,573) Commodity Derivatives, net (12,099) (11,128) (260,892) Interest rate Interest expense 2,202 — — Total derivatives not designated as hedging instruments $ (14,747) $ (28,349) $ (275,465)

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2024
Fair Value Disclosures [Abstract]
Schedule of Company's Assets and Liabilities that are Measured at Fair Value on a Recurring Basis	The following tables present the Company’s assets and liabilities that are measured at fair value on a recurring basis as of December 31, 2024 and 2023, for each fair value hierarchy level: Fair Value Measurements Using: Quoted Prices in Active Markets for Identical Assets Significant Other Significant Unobservable Inputs (Level 1) (Level 2) (Level 3) Total (In thousands) December 31, 2024 Assets: Commodity derivatives $ — $ 7,226 $ — $ 7,226 Provisional oil sales — 2,242 — 2,242 Interest rate derivatives — 2,202 — 2,202 Decommissioning trust fund: Debt securities — 10,653 — 10,653 Total $ — $ 22,323 $ — $ 22,323 December 31, 2023 Assets: Commodity derivatives $ — $ 9,940 $ — $ 9,940 Liabilities: Commodity derivatives — (3,103) — (3,103) Provisional oil sales — (72) — (72) Total $ — $ 6,765 $ — $ 6,765
Schedule of Costs and Fair Values of Investments in Debt Securities in Decommissioning Trust Fund	The following table summarizes the cost and fair value, purchases, proceeds from the sales and maturities, and the unrealized gains (losses) for Kosmos’ portion of the investments in debt securities held by the decommissioning trust at December 31, 2024 and 2023: January 1, December 31, Type of Security Cost Purchases Net Proceeds (1) Unrealized Gain (Loss) Estimated Fair Value 2024 (In thousands) Debt securities $ — $ 10,708 $ — $ (55) $ 10,653 Cash and cash equivalents — 752 101 — 853 Total $ — $ 11,460 $ 101 $ (55) $ 11,506 2023 Debt securities $ — $ — $ — $ — $ — Cash and cash equivalents — — — — — Total $ — $ — $ — $ — $ — (1) Net proceeds includes realized gains or losses, interest income, and fees. The following table presents the costs and fair values of investments in debt securities held in the decommissioning trust fund according to the contractual maturities at December 31, 2024 and 2023: December 31, 2024 December 31, 2023 Cost Estimated Fair Value Cost Estimated Fair Value (In thousands) Less than 5 years $ 10,708 $ 10,653 $ — $ — 5 years to 10 years — — — — Due after 10 years — — — — Total $ 10,708 $ 10,653 $ — $ —
Schedule of Carrying Values and Fair Values of Financial Instruments that are not Carried at Fair Value	The following table presents the carrying values and fair values at December 31, 2024 and 2023: December 31, 2024 December 31, 2023 Carrying Value Fair Value Carrying Value Fair Value (In thousands) 7.125% Senior Notes $ 249,315 $ 246,565 $ 646,912 $ 622,824 7.750% Senior Notes 347,910 339,927 396,718 374,764 7.500% Senior Notes 397,672 379,404 446,291 412,461 8.750% Senior Notes 494,997 470,965 — — 3.125% Convertible Senior Notes 391,603 332,792 — — Facility 900,000 900,000 925,000 925,000 Total $ 2,781,497 $ 2,669,653 $ 2,414,921 $ 2,335,049

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2024
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Changes in Asset Retirement Obligations	The following table summarizes the changes in the Company’s asset retirement obligations: December 31, 2024 2023 (In thousands) Asset retirement obligations: Beginning asset retirement obligations $ 346,786 $ 302,534 Liabilities incurred during period 23,104 16,196 Liabilities settled during period (1,675) (13,082) Revisions in estimated retirement obligations 4,953 11,527 Accretion expense 33,843 29,611 Ending asset retirement obligations $ 407,011 $ 346,786

Equity-based Compensation (Tabl

Equity-based Compensation (Tables)	12 Months Ended
	Dec. 31, 2024
Share-Based Payment Arrangement [Abstract]
Schedule of Outstanding Restricted Stock Units	The following table reflects the outstanding restricted stock units as of December 31, 2024: Service Vesting Weighted- Average Grant-Date Fair Value Market / Service Vesting Restricted Stock Units Weighted-Average Grant-Date Fair Value (In thousands) (In thousands) Outstanding at December 31, 2021: 4,696 $ 3.88 11,233 $ 5.28 Granted(1) 2,820 4.70 3,388 6.98 Forfeited(1) (147) 3.92 (389) 6.21 Vested (2,453) 4.21 (2,191) 5.98 Outstanding at December 31, 2022: 4,916 4.18 12,041 5.61 Granted(1) 2,809 7.61 3,482 12.26 Forfeited(1) (240) 5.65 (203) 8.17 Vested (2,775) 3.86 (2,950) 8.22 Outstanding at December 31, 2023: 4,710 5.77 12,370 6.59 Granted(1) 4,481 6.22 6,232 8.58 Forfeited(1) (386) 6.31 (485) 9.57 Vested (4,052) 3.02 (9,351) 3.91 Outstanding at December 31, 2024: 4,753 6.36 8,766 9.07 __________________________________ (1) The restricted stock units with a combination of market and service vesting criteria may vest between 0% and 200% of the originally granted units depending upon market performance conditions. Awards vesting over or under target shares of 100% results in additional shares granted or forfeited, respectively, in the period the market vesting criteria is determined.
Schedule of Share-based Payment Arrangement, Activity	The following table summarizes certain information related to our share-based payments: Years Ended December 31, 2024 2023 2022 (In thousands) Share-based compensation expense $ 37,951 $ 42,693 $ 34,546 Total tax benefit 6,184 7,482 5,933 Net tax shortfall (windfall) (9,562) (3,201) 673 Fair value of awards vested 82,317 45,098 22,205

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2024
Income Tax Disclosure [Abstract]
Schedule of Components of Income (Loss) Before Income Taxes	Income (loss) before income taxes is composed of the following: Years Ended December 31, 2024 2023 2022 (In thousands) United States $ (162,243) $ (88,458) $ 73,529 Foreign 512,055 460,193 263,538 Income before income taxes $ 349,812 $ 371,735 $ 337,067
Schedule of Components of Provision for Income Taxes Attributable to Income (Loss) Before Income Taxes	The components of the provision for income taxes attributable to our income (loss) before income taxes consist of the following: Years Ended December 31, 2024 2023 2022 (In thousands) Current: United States $ (1,074) $ 865 $ 7,174 Foreign 213,209 264,910 300,829 Total current 212,135 265,775 308,003 Deferred: United States 2,933 551 84 Foreign (55,107) (108,111) (197,571) Total deferred (52,174) (107,560) (197,487) Income tax expense $ 159,961 $ 158,215 $ 110,516
Schedule of Income Tax Expense (Benefit) and Reported Effective Tax Rate	Our reconciliation of income tax expense (benefit) computed by applying our statutory rate and the reported effective tax rate on income or (loss) from continuing operations is as follows: Years Ended December 31, 2024 2023 2022 (In thousands) Tax at statutory rate $ 72,167 $ 78,064 $ 70,784 Foreign income (loss) taxed at different rates 66,634 48,768 20,663 Non-deductible compensation 8,813 5,915 3,012 Non-deductible and other items 7,216 2,243 3,993 Tax shortfall (windfall) on equity-based compensation, net (11,615) (3,201) 673 Change in valuation allowance 72,179 26,426 11,391 Change in statutory tax rate (55,433) — — Total tax expense (benefit) $ 159,961 $ 158,215 $ 110,516 Effective tax rate 46 % 43 % 33 % ______________________________________ (1) The effective tax rate during the years ended December 31, 2024, 2023 and 2022, were impacted by (gains) and losses of $155.3 million, $(4.0) million and $21.0 million, respectively, incurred in jurisdictions in which we are not subject to taxes and therefore do not generate any income tax benefits or where there are valuation allowances offsetting the corresponding deferred tax assets.
Schedule of Tax Effects of Significant Temporary Differences to Deferred Tax Assets and Liabilities	The tax effects of significant temporary differences giving rise to deferred tax assets and liabilities are as follows: December 31, 2024 2023 (In thousands) Deferred tax assets: Foreign capitalized operating expenses $ 247,306 $ 209,453 Foreign net operating losses 34,764 14,458 United States net operating losses 96,945 78,706 United States deferred interest expense 69,051 43,411 Equity compensation 11,164 10,867 Asset retirement obligation and other 98,056 78,024 Total deferred tax assets 557,286 434,919 Valuation allowance (405,831) (333,651) Total deferred tax assets, net 151,455 101,268 Deferred tax liabilities: Depletion, depreciation and amortization related to property and equipment (411,234) (420,066) Other deferred tax liabilities (48,937) (42,087) Total deferred tax liabilities (460,171) (462,153) Net deferred tax liability $ (308,716) $ (360,885)

Net Income (Loss) Per Share (Ta

Net Income (Loss) Per Share (Tables)	12 Months Ended
	Dec. 31, 2024
Earnings Per Share [Abstract]
Schedule of Reconciliation Between Compute Basic and Diluted Net Income Per Share and Weighted Average Share Outstanding	Basic net income (loss) per share is computed as (i) net income (loss), (ii) less income allocable to participating securities (iii) divided by weighted average basic shares outstanding. The Company’s diluted net income (loss) per share is computed as (i) basic net income (loss), (ii) plus diluted adjustments to income allocable to participating securities (iii) divided by weighted average diluted shares outstanding. Years Ended December 31, 2024 2023 2022 (In thousands, except per share data) Numerator: Net income allocable to common stockholders $ 189,851 $ 213,520 $ 226,551 Denominator: Weighted average number of shares outstanding: Basic 470,844 459,641 455,346 Restricted stock units(1) 5,847 21,429 19,511 Diluted 476,691 481,070 474,857 Net income per share: Basic $ 0.40 $ 0.46 $ 0.50 Diluted $ 0.40 $ 0.44 $ 0.48 ______________________________________ (1) Our restricted stock units are not considered to be participating securities and, therefore, are excluded from the basic net income (loss) per share calculation. (2) For the years ended December 31, 2024, 2023 and 2022, we excluded 3.3 million, 0.0 million and 0.1 million outstanding restricted stock units, respectively, from the computations of diluted net income per share because the effect would have been anti‑dilutive.

Additional Financial Informat_2

Additional Financial Information (Tables)	12 Months Ended
	Dec. 31, 2024
Additional Financial Information
Schedule of Accrued Liabilities	Accrued liabilities consisted of the following: December 31, 2024 2023 (In thousands) Accrued liabilities: Exploration, development and production $ 78,163 $ 90,054 Revenue payable 18,909 20,506 Current asset retirement obligations 125 2,808 General and administrative expenses 39,071 29,766 Interest 47,228 36,410 Income taxes 52,262 111,212 Taxes other than income 1,222 1,029 Derivatives 844 1,372 Other 7,130 9,658 $ 244,954 $ 302,815
Schedule of Other Expenses, Net	Other expenses, net incurred during the period is comprised of the following: Years Ended December 31, 2024 2023 2022 (In thousands) Loss on disposal of inventory $ 1,835 $ 7,372 $ 1,521 Gain on insurance settlements — — (7,000) (Gain) loss on asset retirement obligations liability settlements (3,169) 6,034 (3,278) Other, net 19,037 10,250 (297) Other expenses, net $ 17,703 $ 23,656 $ (9,054)

Business Segment Information (T

Business Segment Information (Tables)	12 Months Ended
	Dec. 31, 2024
Segment Reporting [Abstract]
Schedule of Business Segment Information	Financial information for each reporting segment is presented below: Ghana Equatorial Guinea Mauritania / Senegal Gulf of America Corporate & Other Eliminations Total (in thousands) Years ended December 31, 2024 Revenues and other income: Oil and gas revenue $ 1,044,562 $ 260,675 $ — $ 370,121 $ — $ — $ 1,675,358 Other income, net 48 — — 2,895 171,706 (174,445) 204 Total revenues and other income 1,044,610 260,675 — 373,016 171,706 (174,445) 1,675,562 Costs and expenses: Oil and gas production 164,385 136,398 93,412 136,319 — — 530,514 Exploration expenses 3,572 73,009 16,973 21,447 4,906 — 119,907 General and administrative 13,718 6,129 10,974 19,326 212,354 (162,346) 100,155 Depletion, depreciation and amortization 203,501 65,178 950 185,068 2,077 — 456,774 Interest and other financing costs, net(1) 51,302 (2,697) (146,952) (12,607) 199,552 — 88,598 Derivatives, net — — — — 12,099 — 12,099 Other expenses, net 14,894 (4,673) 14,764 4,782 35 (12,099) 17,703 Total costs and expenses 451,372 273,344 (9,879) 354,335 431,023 (174,445) 1,325,750 Income before income taxes 593,238 (12,669) 9,879 18,681 (259,317) — 349,812 Income tax expense 201,006 (41,217) — 14,179 (14,007) — 159,961 Net income (loss) $ 392,232 $ 28,548 $ 9,879 $ 4,502 $ (245,310) $ — $ 189,851 Consolidated capital expenditures $ 139,130 $ 177,196 $ 324,798 $ 181,160 $ 6,529 $ — $ 828,813 As of December 31, 2024 Property and equipment, net $ 986,693 $ 482,223 $ 2,057,786 $ 901,012 $ 16,507 $ — $ 4,444,221 Total assets $ 3,682,493 $ 2,313,856 $ 3,188,067 $ 4,094,116 $ 25,867,010 $ (33,836,554) $ 5,308,988 ______________________________________ (1) Interest expense is recorded based on actual third-party and intercompany debt agreements. Capitalized interest is recorded on the business unit where the assets reside. Ghana Equatorial Guinea Mauritania / Senegal Gulf of America Corporate & Other Eliminations Total (in thousands) Year ended December 31, 2023 Revenues and other income: Oil and gas revenue $ 1,062,482 $ 267,494 $ — $ 371,632 $ — $ — $ 1,701,608 Other income, net (403) 10 — 3,327 157,770 (160,777) (73) Total revenues and other income 1,062,079 267,504 — 374,959 157,770 (160,777) 1,701,535 Costs and expenses: Oil and gas production 175,265 114,411 — 100,421 — — 390,097 Exploration expenses 872 7,915 15,784 11,950 5,757 — 42,278 General and administrative 12,913 5,555 9,354 22,076 199,283 (149,649) 99,532 Depletion, depreciation and amortization 240,998 51,750 917 149,482 1,780 — 444,927 Impairment of long-lived assets 222,278 — — — — 222,278 Interest and other financing costs, net(1) 56,988 (2,942) (119,697) 6,236 155,319 — 95,904 Derivatives, net — — — — 11,128 — 11,128 Other expenses, net 7,963 3,208 7,997 10,506 5,110 (11,128) 23,656 Total costs and expenses 717,277 179,897 (85,645) 300,671 378,377 (160,777) 1,329,800 Income (loss) before income taxes 344,802 87,607 85,645 74,288 (220,607) — 371,735 Income tax expense (benefit) 122,704 35,666 — 13,643 (13,798) — 158,215 Net income (loss) $ 222,098 $ 51,941 $ 85,645 $ 60,645 $ (206,809) $ — $ 213,520 Consolidated capital expenditures $ 276,849 $ 74,573 $ 276,484 $ 212,431 $ 9,662 $ — $ 849,999 As of December 31, 2023 Property and equipment, net $ 1,036,651 $ 424,030 $ 1,788,214 $ 893,293 $ 18,041 $ — $ 4,160,229 Total assets $ 3,252,235 $ 1,918,131 $ 2,642,098 $ 3,988,805 $ 21,599,662 $ (28,462,797) $ 4,938,134 ______________________________________ (1) Interest expense is recorded based on actual third-party and intercompany debt agreements. Capitalized interest is recorded on the business unit where the assets reside. Ghana (2) Equatorial Guinea Mauritania / Senegal Gulf of America (3) Corporate & Other Eliminations Total (in thousands) Year ended December 31, 2022 Revenues and other income: Oil and gas revenue $ 1,350,962 $ 346,783 $ — $ 547,610 $ — $ — $ 2,245,355 Gain on sale of assets — — — 471 50,000 — 50,471 Other income, net 428 3,350 — 2,405 386,002 (388,236) 3,949 Total revenues and other income 1,351,390 350,133 — 550,486 436,002 (388,236) 2,299,775 Costs and expenses: Oil and gas production 212,729 90,602 — 105,968 — — 409,299 Exploration expenses 14,987 7,378 82,526 22,763 6,576 — 134,230 General and administrative 15,310 6,703 9,798 15,794 180,594 (127,343) 100,856 Depletion, depreciation and amortization 289,058 53,765 412 153,407 1,614 — 498,256 Impairment of long-lived assets 450,357 — — (388) — — 449,969 Interest and other financing costs, net(1) 64,620 (2,494) (69,644) 11,180 114,598 — 118,260 Derivatives, net — — — — 260,892 — 260,892 Other expenses, net 233,785 8,397 (1,178) 10,339 496 (260,893) (9,054) Total costs and expenses 1,280,846 164,351 21,914 319,063 564,770 (388,236) 1,962,708 Income (loss) before income taxes 70,544 185,782 (21,914) 231,423 (128,768) — 337,067 Income tax expense (benefit) 28,091 72,814 — (1,010) 10,621 — 110,516 Net income (loss) $ 42,453 $ 112,968 $ (21,914) $ 232,433 $ (139,389) $ — $ 226,551 Consolidated capital expenditures $ 98,540 $ 36,036 $ 407,982 $ 111,016 $ (41,986) $ — $ 611,588 As of December 31, 2022 Property and equipment, net $ 1,202,937 $ 396,737 $ 1,396,884 $ 829,242 $ 16,847 $ — $ 3,842,647 Total assets $ 2,886,242 $ 1,463,211 $ 2,026,776 $ 3,695,641 $ 19,554,236 $ (25,046,118) $ 4,579,988 ______________________________________ (1) Interest expense is recorded based on actual third-party and intercompany debt agreements. Capitalized interest is recorded on the business unit where the assets reside. (2) Includes activity related to the interest pre-empted by Tullow prior to the March 17, 2022 closing date of the Tullow pre-emption transaction. Additionally, cash consideration of $118.2 million is included as a reduction in Consolidated capital expenditures for the year ended December 31, 2022. (3) Includes activity related to our acquisition of an additional interest in the Kodiak oil field commencing June 9, 2022, the acquisition date. Additionally, cash consideration paid of $29.0 million is included in the Consolidated capital expenditures for the year ended December 31, 2022. Years Ended December 31, 2024 2023 2022 (In thousands) Consolidated capital expenditures: Consolidated Statements of Cash Flows - Investing activities: Oil and gas assets $ 933,659 $ 932,603 $ 787,297 Acquisition of oil and gas properties — — 22,078 Proceeds on sale of assets — — (168,703) Adjustments: Changes in capital accruals 13,392 6,732 396 Exploration expense, excluding unsuccessful well costs and leasehold impairments(1) 45,418 40,070 47,289 Capitalized interest (168,715) (138,738) (84,343) Other 5,059 9,332 7,574 Total consolidated capital expenditures $ 828,813 $ 849,999 $ 611,588 ______________________________________ (1) Unsuccessful well costs are included in oil and gas assets when incurred.

Organization (Details)

Organization (Details)	12 Months Ended
	Dec. 31, 2024 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of operating geographic areas	4

Accounting Policies - Schedule

Accounting Policies - Schedule of Cash, Cash Equivalents, and Restricted Cash (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Accounting Policies [Abstract]
Cash and cash equivalents	$ 84,972	$ 95,345	$ 183,405
Restricted cash - long-term	305	3,416	3,416
Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows	$ 85,277	$ 98,761	$ 186,821	$ 174,896

Accounting Policies - Narrative

Accounting Policies - Narrative (Details)	12 Months Ended
	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Sep. 30, 2024	Apr. 30, 2024	Mar. 31, 2024	Oct. 31, 2021	Mar. 31, 2021	Apr. 30, 2019
Receivables
Allowance for doubtful accounts	$ 13,600,000	$ 9,800,000
Inventories
Materials and supplies inventory	167,500,000	143,000,000
Hydrocarbons inventory	3,400,000	9,100,000
Write down of materials and supplies	1,835,000	7,372,000	$ 1,521,000
Revenue Recognition
Oil and gas imbalances	$ 0	$ 0
Minimum | Capitalized Interest
Capitalized Interest
Expected construction period for capitalization of interest costs on major projects (in years)	1 year
Facility
Cash, Cash Equivalents and Restricted Cash
Net leverage ratio	2.54	2.50			2.50
Facility | Senior Notes
Cash, Cash Equivalents and Restricted Cash
Net leverage ratio	2.54
Facility Interest Or Senior Notes
Cash, Cash Equivalents and Restricted Cash
Period for contractual future interest payments	6 months
Restricted cash required	$ 66,000,000
7.125% Senior Notes | Senior Notes
Cash, Cash Equivalents and Restricted Cash
Interest rate (as a percent)	7.125%								7.125%
7.750% Senior Notes | Senior Notes
Cash, Cash Equivalents and Restricted Cash
Interest rate (as a percent)	7.75%						7.75%
7.500% Senior Notes | Senior Notes
Cash, Cash Equivalents and Restricted Cash
Interest rate (as a percent)	7.50%							7.50%
8.750% Senior Notes | Senior Notes
Cash, Cash Equivalents and Restricted Cash
Interest rate (as a percent)	8.75%			8.75%
3.125% Convertible Senior Notes | Senior Notes
Cash, Cash Equivalents and Restricted Cash
Interest rate (as a percent)	3.125%	3.125%				3.125%

Accounting Policies - Schedul_2

Accounting Policies - Schedule of Useful Lives (Details)	Dec. 31, 2024
Minimum
Property, Plant and Equipment [Line Items]
Estimated useful lives	1 year
Minimum | Leasehold improvements
Property, Plant and Equipment [Line Items]
Estimated useful lives	1 year
Minimum | Office furniture, fixtures and computer equipment
Property, Plant and Equipment [Line Items]
Estimated useful lives	3 years
Maximum
Property, Plant and Equipment [Line Items]
Estimated useful lives	8 years
Maximum | Leasehold improvements
Property, Plant and Equipment [Line Items]
Estimated useful lives	8 years
Maximum | Office furniture, fixtures and computer equipment
Property, Plant and Equipment [Line Items]
Estimated useful lives	7 years

Accounting Policies - Summary o

Accounting Policies - Summary of Oil and Gas Revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Provisional oil sales contracts	$ (14,747)	$ (28,349)	$ (275,465)
Oil and gas revenue	1,675,358	1,701,608	2,245,355
Oil and gas revenue
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,680,208	1,718,829	2,259,928
Provisional oil sales contracts	(4,850)	(17,221)	(14,573)
Oil and gas revenue	1,675,358	1,701,608	2,245,355
Oil and gas revenue | Equatorial Guinea
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	257,961	273,280	349,443
Oil and gas revenue | Ghana
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	1,052,126	1,073,917	1,362,875
Oil and gas revenue | Gulf of America
Disaggregation of Revenue [Line Items]
Total revenues from contracts with customers	$ 370,121	$ 371,632	$ 547,610

Acquisitions and Divestitures -

Acquisitions and Divestitures - 2024 Transactions (Details) - Keathley Canyon Blocks 920 And 964 - Tiberius	1 Months Ended
	Mar. 31, 2024	Feb. 29, 2024
Business Acquisition [Line Items]
Participating interest percentage acquired (as a percent)	16.70%
Participation interest (as a percent)	50%	33.30%

Acquisitions and Divestitures_2

Acquisitions and Divestitures - 2023 Transactions (Details)	1 Months Ended
	Feb. 28, 2023	Nov. 30, 2023	Feb. 28, 2023 a	Feb. 28, 2023 km²
Block EG-01 Offshore Equatorial Guinea | Petroleum Contract
Business Acquisition [Line Items]
Participation interest (as a percent)	24%
Area of block			59,400	240
First exploration period	3 years
Cayar Offshore Profond Block
Business Acquisition [Line Items]
Participation interest (as a percent)		90%
Cayar Offshore Profond Block | PETROSEN
Business Acquisition [Line Items]
Participation interest (as a percent)		10%
Increase participation interest, (as a percent)		0.35

Acquisitions and Divestitures_3

Acquisitions and Divestitures - 2022 Transactions (Details) $ in Thousands

1 Months Ended

3 Months Ended

12 Months Ended

Oct. 31, 2022 USD ($)

Sep. 30, 2022 USD ($) transaction

Jun. 30, 2022 USD ($)

Mar. 31, 2022 USD ($)

Oct. 31, 2021

Mar. 31, 2022 USD ($)

Dec. 31, 2024 USD ($)

Dec. 31, 2023 USD ($)

Dec. 31, 2022 USD ($)

Oct. 30, 2022

May 31, 2022

Feb. 28, 2022

Sep. 30, 2021

Business Acquisition [Line Items]

Proceeds on sale of assets

$ 0

$ 0

$ 168,703

Jubilee Unit Area

Business Acquisition [Line Items]

Participating interest percentage (as a percent)

24.10%

Jubilee Unit Area | Deepwater Tano Block Joint Operating Agreement

Business Acquisition [Line Items]

Participating interest percentage after pre-emption (as a percent)

38.60%

38.60%

TEN Fields

Business Acquisition [Line Items]

Participating interest percentage (as a percent)

17%

TEN Fields | Deepwater Tano Block Joint Operating Agreement

Business Acquisition [Line Items]

Participating interest percentage after pre-emption (as a percent)

20.40%

20.40%

Winterfell Green Canyon Blocks

Business Acquisition [Line Items]

Number of transactions | transaction

2

Marubeni | Kodiak Field

Business Acquisition [Line Items]

Participating interest percentage acquired (as a percent)

5.90%

Participating interest percentage after acquired interest (as a percent)

35%

Total purchase price

$ 29,000

29,000

Initial purchase price

38,300

Business combination, purchase price adjustments

9,300

Assets acquired and liabilities assumed

$ 27,100

Participation interest (as a percent)

29.10%

Anadarko WCTP | Jubilee Unit Area

Business Acquisition [Line Items]

Participating interest percentage acquired (as a percent)

18%

Participating interest percentage after acquired interest (as a percent)

42.10%

42.10%

Anadarko WCTP | TEN Fields

Business Acquisition [Line Items]

Participating interest percentage acquired (as a percent)

11.10%

Participating interest percentage after acquired interest (as a percent)

28.10%

28.10%

Tullow | Jubilee Unit Area And Ten Fields

Business Acquisition [Line Items]

Proceeds on sale of assets

$ 118,200

$ 118,200

Reduction from divestiture

$ 175,500

Green Canyon Blocks 943, 944, 987 And 988 | Winterfell Green Canyon Blocks

Business Acquisition [Line Items]

Participating interest percentage acquired (as a percent)

3.20%

5.50%

Participating interest percentage after acquired interest (as a percent)

25%

Green Canyon Blocks 899 And 900 | Winterfell Green Canyon Blocks

Business Acquisition [Line Items]

Participating interest percentage acquired (as a percent)

1.40%

1.50%

Participating interest percentage after acquired interest (as a percent)

37.80%

Green Canyon Blocks 943, 944, 987, 988, 899 And 900 | Winterfell Green Canyon Blocks

Business Acquisition [Line Items]

Payments to acquire businesses, gross

$ 6,600

$ 9,600

Block S Offshore Equatorial Guinea | Farm-out Agreement

Business Acquisition [Line Items]

Participation interest (as a percent)

34%

Block S Offshore Equatorial Guinea | Farm-out Agreement | Panoro Energy ASA

Business Acquisition [Line Items]

Participation interest (as a percent)

6%

Proceeds on sale of assets

$ 1,800

Receivables - Schedule of Recei

Receivables - Schedule of Receivables (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Dec. 31, 2023
Receivables [Abstract]
Joint interest billings, net	$ 33,120	$ 35,632
Oil sales	89,694	64,958
Other current receivables	42,145	20,143
Total receivables	164,959	120,733
Long-term receivables	$ 385,463	$ 325,181

Receivables - Narrative (Detail

Receivables - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Dec. 31, 2021	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Aug. 31, 2021
BP Operator
Oil and Gas Joint Interest Billing Receivables [Line Items]
Long-term receivables						$ 200.2
Settlement of payment obligation of capital expenditures	$ 67.8	$ 132.4
National Oil Companies of Mauritania And Senegal | Carry Advance Agreements
Oil and Gas Joint Interest Billing Receivables [Line Items]
Long-term receivables			$ 280.1	$ 259.2
Accrued interest on balance due			56.6	37.3
Interest income, long-term notes receivable			$ 19.3	$ 15.9	$ 10.1
Greater Tortue FPSO | BP Operator
Oil and Gas Joint Interest Billing Receivables [Line Items]
Contract liability, noncurrent						$ 200.2

Property and Equipment - Schedu

Property and Equipment - Schedule of Property and Equipment (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Oil and gas properties:
Proved properties	$ 8,342,353	$ 7,600,252
Unproved properties	386,292	423,050
Total oil and gas properties	8,728,645	8,023,302
Accumulated depletion	(4,288,215)	(3,868,946)
Oil and gas properties, net	4,440,430	4,154,356
Other property	66,675	65,095
Accumulated depreciation	(62,884)	(59,222)
Other property, net	3,791	5,873
Property and equipment, net	$ 4,444,221	$ 4,160,229	$ 3,842,647

Property and Equipment - Narrat

Property and Equipment - Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Aug. 31, 2021
Property, Plant and Equipment [Line Items]
Depletion expense	$ 419,300,000	$ 411,600,000	$ 471,400,000
Depreciation expense	3,700,000	3,700,000	3,600,000
Impairment of long-lived assets	0	222,278,000	449,969,000
Capitalized exploratory costs	37,175,000	0	62,818,000
BP Operator | Greater Tortue FPSO
Property, Plant and Equipment [Line Items]
Contract liability, noncurrent				$ 200,200,000
TEN Fields
Property, Plant and Equipment [Line Items]
Impairment of long-lived assets		$ 222,300,000	$ 450,000,000
S-5 Exploration Well
Property, Plant and Equipment [Line Items]
Capitalized exploratory costs	$ 37,600,000

Suspended Well Costs - Schedule

Suspended Well Costs - Schedule of Suspended Well Costs (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2024 USD ($) project	Dec. 31, 2023 USD ($) project	Dec. 31, 2022 USD ($) project
Reconciliation of capitalized exploratory well costs on completed wells
Beginning balance	$ 211,959	$ 145,957	$ 218,180
Additions to capitalized exploratory well costs pending the determination of proved reserves	21,418	66,002	25,209
Reclassification due to determination of proved reserves	0	0	(34,614)
Capitalized exploratory well costs charged to expense	(37,175)	0	(62,818)
Ending balance	196,202	211,959	145,957
Aging of capitalized exploratory well costs and number of projects for which exploratory well costs were capitalized for more than one year
Exploratory well costs capitalized for a period of one year or less	0	54,274	0
Exploratory well costs capitalized for a period of one to five years	63,552	34,775	75,941
Exploratory well costs capitalized for a period of six to ten years	132,650	122,910	70,016
Ending balance	$ 196,202	$ 211,959	$ 145,957
Number of projects that have exploratory well costs that have been capitalized for a period greater than one year | project	2	2	2

Suspended Well Costs - Narrativ

Suspended Well Costs - Narrative (Details) - km	1 Months Ended
	Mar. 31, 2024	Sep. 30, 2019	Feb. 29, 2024
Capitalized Contract Cost [Line Items]
License extension period	2 years
Keathley Canyon Blocks 920 And 964 | Tiberius
Capitalized Contract Cost [Line Items]
Participating interest percentage acquired (as a percent)	16.70%
Participation interest (as a percent)	50%		33.30%
Yakaar and Teranga Discoveries
Capitalized Contract Cost [Line Items]
Distance from Yakaar-2 well to Yakaar-1 exploration well		9

Leases - Narrative (Details)

Leases - Narrative (Details)	Dec. 31, 2024
Minimum
Lessee, Lease, Description [Line Items]
Operating lease, initial term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Operating lease, initial term	10 years

Leases - Schedule of Components

Leases - Schedule of Components of Lease Cost (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Lessee, Lease, Description [Line Items]
Operating lease cost	$ 3,864	$ 3,866	$ 3,882
Variable lease cost	1,963	1,766	1,825
Short-term lease cost	12,281	17,464	13,970
Total lease cost	18,108	23,096	19,677
Short-Term Drilling Contracts
Lessee, Lease, Description [Line Items]
Short-term lease cost	$ 10,700	$ 16,000	$ 12,400

Leases - Schedule of Other Info

Leases - Schedule of Other Information Leases (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Dec. 31, 2023
Leases [Abstract]
Other assets (right-of-use assets)	$ 12,294	$ 14,234
Accrued liabilities (current maturities of leases)	2,816	2,492
Other long-term liabilities (non-current maturities of leases)	$ 12,745	$ 15,576
Weighted average remaining lease term	4 years 7 months 6 days	5 years 7 months 6 days
Weighted average discount rate	9.80%	9.80%
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Other Assets	Other Assets
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Accrued liabilities	Accrued liabilities
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Other long-term liabilities	Other long-term liabilities

Leases - Schedule of Supplement

Leases - Schedule of Supplemental Cash Flow Information Related to Leases (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Leases [Abstract]
Operating cash flows for operating leases	$ 7,683	$ 7,256	$ 7,170
Investing cash flows for operating leases	$ 10,746	$ 16,029	$ 12,449

Leases - Schedule of Future Min

Leases - Schedule of Future Minimum Rental Commitments (Details) $ in Thousands	Dec. 31, 2024 USD ($)
Leases [Abstract]
2025	$ 4,189
2026	4,260
2027	4,201
2028	3,844
2029	2,808
Thereafter	0
Total undiscounted lease payments	19,302
Less: Imputed interest	(3,741)
Total lease liabilities	$ 15,561

Debt - Schedule of Instruments

Debt - Schedule of Instruments (Details) - USD ($)	Dec. 31, 2024	Sep. 30, 2024	Mar. 31, 2024	Dec. 31, 2023	Oct. 31, 2021	Mar. 31, 2021	Apr. 30, 2019
Debt Instrument [Line Items]
Total long-term debt	$ 2,800,274,000			$ 2,425,000,000
Unamortized deferred financing costs and discounts	(55,562,000)			(34,086,000)
Long-term debt, net	2,744,712,000			2,390,914,000
Senior Notes
Debt Instrument [Line Items]
Unamortized deferred financing costs and discounts	(14,100,000)			13,300,000
Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Unamortized deferred financing costs and discounts	(30,400,000)			20,800,000
Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Total long-term debt	$ 900,000,000			925,000,000
7.125% Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)	7.125%						7.125%
Total long-term debt	$ 250,000,000			650,000,000
7.750% Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)	7.75%				7.75%
Total long-term debt	$ 350,000,000			400,000,000
7.500% Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)	7.50%					7.50%
Total long-term debt	$ 400,274,000			450,000,000
8.750% Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)	8.75%	8.75%
Total long-term debt	$ 500,000,000			$ 0
3.125% Convertible Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)	3.125%		3.125%	3.125%
Total long-term debt	$ 400,000,000			$ 0
Unamortized deferred financing costs and discounts	$ 11,100,000			$ 0

Debt - Facility (Details)

Debt - Facility (Details)

1 Months Ended

3 Months Ended

12 Months Ended

Sep. 30, 2024 USD ($) lender

Apr. 30, 2024 USD ($)

Jun. 30, 2024 USD ($)

Dec. 31, 2024 USD ($)

Dec. 31, 2023 USD ($)

Dec. 31, 2022 USD ($)

Sep. 30, 2027

Oct. 31, 2024 USD ($)

Mar. 31, 2024

Oct. 31, 2023 USD ($)

Oct. 31, 2021

Mar. 31, 2021

Apr. 30, 2019

Debt Instrument [Line Items]

Debt modifications and extinguishments

$ 25,173,000

$ 1,503,000

$ 192,000

Total long-term debt

$ 2,800,274,000

$ 2,425,000,000

Facility

Debt Instrument [Line Items]

Net leverage ratio

2.50

2.54

2.50

Field life cover ratio

1.50

Interest cover ratio

2.25

Debt cover ratio

3.50

Facility | Revolving Credit Facility

Debt Instrument [Line Items]

Total long-term debt

$ 900,000,000

$ 925,000,000

Facility | Senior Notes

Debt Instrument [Line Items]

Net leverage ratio

2.54

Facility | Minimum

Debt Instrument [Line Items]

Loan life cover ratio

1.10

Facility | Maximum | Forecast

Debt Instrument [Line Items]

Loan life cover ratio

1.30

Facility Interest Or Senior Notes

Debt Instrument [Line Items]

Interval period for payment of interest (in months)

6 months

Restricted cash required

$ 66,000,000

7.125% Senior Notes | Senior Notes

Debt Instrument [Line Items]

Total long-term debt

$ 250,000,000

650,000,000

Interest rate (as a percent)

7.125%

7.125%

7.750% Senior Notes | Senior Notes

Debt Instrument [Line Items]

Total long-term debt

$ 350,000,000

400,000,000

Interest rate (as a percent)

7.75%

7.75%

7.500% Senior Notes | Senior Notes

Debt Instrument [Line Items]

Total long-term debt

$ 400,274,000

450,000,000

Interest rate (as a percent)

7.50%

7.50%

8.750% Senior Notes | Senior Notes

Debt Instrument [Line Items]

Total long-term debt

$ 500,000,000

0

Interest rate (as a percent)

8.75%

8.75%

3.125% Convertible Senior Notes | Senior Notes

Debt Instrument [Line Items]

Total long-term debt

$ 400,000,000

$ 0

Interest rate (as a percent)

3.125%

3.125%

3.125%

Revolving Credit Facility | Facility

Debt Instrument [Line Items]

Maximum borrowing capacity

$ 1,350,000,000

$ 1,350,000,000

$ 1,350,000,000

$ 1,250,000,000

Debt extension (in years)

3 years

Available borrowing base

$ 1,210,000,000

Debt modifications and extinguishments

$ 22,000,000

Number of new lenders | lender

2

Increase current total commitments

$ 145,000,000

Undrawn availability

$ 450,000,000

Interval period for payment of interest (in months)

6 months

Commitment fees percentage

30%

Unavailable capacity commitment fee percentage

20%

Availability period of revolving-credit

1 month

Revolving Credit Facility | Facility | Minimum

Debt Instrument [Line Items]

Increase in interest margin (as a percent)

0.0025

Applicable margin (as a percent)

4%

Revolving Credit Facility | Facility | Maximum

Debt Instrument [Line Items]

Increase in interest margin (as a percent)

0.0050

Applicable margin (as a percent)

5.50%

Letter of Credit | Facility

Debt Instrument [Line Items]

Letters of credit issued

$ 0

Debt - Corporate Revolver (Deta

Debt - Corporate Revolver (Details) - Revolving Credit Facility - Corporate Revolver - USD ($) $ in Millions	Apr. 30, 2024	Apr. 01, 2024	Mar. 31, 2022
Debt Instrument [Line Items]
Undrawn availability			$ 250
Maximum borrowing capacity	$ 165	$ 250

Debt - Senior Notes and Capped

Debt - Senior Notes and Capped Call Transaction (Details)		1 Months Ended									12 Months Ended
	Sep. 24, 2024 USD ($)	Sep. 30, 2024 USD ($)	Mar. 31, 2024 USD ($) $ / shares	Mar. 31, 2024 USD ($) $ / shares	Mar. 31, 2024 USD ($) well_option $ / shares	Mar. 31, 2024 USD ($) $ / shares	Mar. 31, 2024 USD ($) tradingDay $ / shares	Oct. 31, 2021 USD ($)	Mar. 31, 2021 USD ($)	Apr. 30, 2019 USD ($)	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)
Debt Instrument [Line Items]
Repayments of senior notes											$ 499,515,000	$ 0	$ 0
Purchase of capped call transactions											$ 49,800,000	$ 0	$ 0
7.125% Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)										7.125%	7.125%
Debt, face amount										$ 650,000,000
Proceeds from debt, net of issuance costs										$ 640,000,000
Repayments of senior notes	$ 400,000,000
7.125% Senior Notes | Senior Notes | Debt Instrument, Redemption, Change Of Control
Debt Instrument [Line Items]
Redemption price, as a percent of principal amount (as a percent)										101%
7.125% Senior Notes | Senior Notes | Debt Instrument, Redemption, Sell Of Assets
Debt Instrument [Line Items]
Redemption price, as a percent of principal amount (as a percent)										100%
7.875% Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)										7.875%
7.750% Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)								7.75%			7.75%
Debt, face amount								$ 400,000,000
Proceeds from debt, net of issuance costs								$ 395,000,000
Repayments of senior notes	50,000,000
7.750% Senior Notes | Senior Notes | Debt Instrument, Redemption, Change Of Control
Debt Instrument [Line Items]
Redemption price, as a percent of principal amount (as a percent)								101%
7.750% Senior Notes | Senior Notes | Debt Instrument, Redemption, Sell Of Assets
Debt Instrument [Line Items]
Redemption price, as a percent of principal amount (as a percent)								100%
7.500% Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)									7.50%		7.50%
Debt, face amount									$ 450,000,000
Proceeds from debt, net of issuance costs									$ 444,400,000
Repayments of senior notes	$ 49,700,000
7.500% Senior Notes | Senior Notes | Debt Instrument, Redemption, Change Of Control
Debt Instrument [Line Items]
Redemption price, as a percent of principal amount (as a percent)									101%
7.500% Senior Notes | Senior Notes | Debt Instrument, Redemption, Sell Of Assets
Debt Instrument [Line Items]
Redemption price, as a percent of principal amount (as a percent)									100%
8.750% Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)		8.75%									8.75%
Debt, face amount		$ 500,000,000
Proceeds from debt, net of issuance costs		$ 494,900,000
Maximum percentage of principal amount available to be redeemed with proceeds from equity offerings (as a percent)		40%
8.750% Senior Notes | Senior Notes | Debt Instrument, Redemption, Change Of Control
Debt Instrument [Line Items]
Redemption price, as a percent of principal amount (as a percent)		101%
8.750% Senior Notes | Senior Notes | Debt Instrument, Redemption, Sell Of Assets
Debt Instrument [Line Items]
Redemption price, as a percent of principal amount (as a percent)		100%
8.750% Senior Notes | Senior Notes | Debt Instrument Redemption, Maximum
Debt Instrument [Line Items]
Redemption price, as a percent of principal amount (as a percent)		108.75%
8.750% Senior Notes | Senior Notes | Debt Instrument, Redemption, Make-Whole Premium
Debt Instrument [Line Items]
Redemption price, as a percent of principal amount (as a percent)		100%
3.125% Convertible Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)			3.125%	3.125%	3.125%	3.125%	3.125%				3.125%	3.125%
Debt, face amount			$ 400,000,000	$ 400,000,000	$ 400,000,000	$ 400,000,000	$ 400,000,000
Proceeds from debt, net of issuance costs				$ 390,400,000
Redemption price, as a percent of principal amount (as a percent)			100%
Threshold trading days					20		20
Threshold consecutive trading days | well_option					30
Threshold percentage of stock price trigger			130%
Debt instrument, number of business days			5 years	5 years	5 years	5 years	5 years
Debt instrument, consecutive trading period			5 years	5 years	5 years	5 years	5 years
Percent of measurement period of conversion rate (as a percent)			0.98	0.98	0.98	0.98	0.98
Debt instrument, conversion ratio			0.1424501
Debt instrument, conversion price (in dollars per share) | $ / shares			$ 7.02	$ 7.02	$ 7.02	$ 7.02	$ 7.02
Debt instrument, consecutive trading period based on daily conversion value | well_option					40
Aggregate amount outstanding and not subject to redemption											$ 75,000,000
Unamortized deferred financing costs			$ 9,600,000	$ 9,600,000	$ 9,600,000	$ 9,600,000	$ 9,600,000
Debt instrument, interest rate (as a percent)											3.70%
Purchase of capped call transactions				$ 49,800,000
Debt instrument, capped call transactions, initial cap price (in dollars per share) | $ / shares						$ 10.80
Premium over last reported price of common stock (as a percent)			100%
3.125% Convertible Senior Notes | Senior Notes | Maximum
Debt Instrument [Line Items]
Threshold trading days | tradingDay							41
Bridge Notes | Senior Notes
Debt Instrument [Line Items]
Debt, face amount								$ 400,000,000

Debt - Schedule of Redemption P

Debt - Schedule of Redemption Price (Details) - Senior Notes	1 Months Ended
	Sep. 30, 2024	Oct. 31, 2021	Mar. 31, 2021	Apr. 30, 2019	Dec. 31, 2024
7.125% Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)				7.125%	7.125%
7.125% Senior Notes | Debt Instrument, Redemption, Period One
Debt Instrument [Line Items]
Redemption price percentage (as a percent)				103.563%
7.125% Senior Notes | Debt Instrument, Redemption, Period Two
Debt Instrument [Line Items]
Redemption price percentage (as a percent)				101.781%
7.125% Senior Notes | Debt Instrument, Redemption, Period Three
Debt Instrument [Line Items]
Redemption price percentage (as a percent)				100%
7.750% Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)		7.75%			7.75%
7.750% Senior Notes | Debt Instrument, Redemption, Period One
Debt Instrument [Line Items]
Redemption price percentage (as a percent)		103.875%
7.750% Senior Notes | Debt Instrument, Redemption, Period Two
Debt Instrument [Line Items]
Redemption price percentage (as a percent)		101.938%
7.750% Senior Notes | Debt Instrument, Redemption, Period Three
Debt Instrument [Line Items]
Redemption price percentage (as a percent)		100%
7.500% Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)			7.50%		7.50%
7.500% Senior Notes | Debt Instrument, Redemption, Period One
Debt Instrument [Line Items]
Redemption price percentage (as a percent)			103.75%
7.500% Senior Notes | Debt Instrument, Redemption, Period Two
Debt Instrument [Line Items]
Redemption price percentage (as a percent)			101.875%
7.500% Senior Notes | Debt Instrument, Redemption, Period Three
Debt Instrument [Line Items]
Redemption price percentage (as a percent)			100%
8.750% Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)	8.75%				8.75%
8.750% Senior Notes | Debt Instrument, Redemption, Period One
Debt Instrument [Line Items]
Redemption price percentage (as a percent)	104.375%
8.750% Senior Notes | Debt Instrument, Redemption, Period Two
Debt Instrument [Line Items]
Redemption price percentage (as a percent)	102.188%
8.750% Senior Notes | Debt Instrument, Redemption, Period Three
Debt Instrument [Line Items]
Redemption price percentage (as a percent)	100%

Debt - Schedule of Principal De

Debt - Schedule of Principal Debt Repayments (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Dec. 31, 2023
Scheduled maturities of debt during the five year period and thereafter
Total	$ 2,800,274	$ 2,425,000
2025	0
2026	250,000
2027	350,000
2028	746,319
2029	553,955
Thereafter	$ 900,000

Debt - Schedule of Interest and

Debt - Schedule of Interest and Other Financing Costs, Net (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Debt Disclosure [Abstract]
Interest expense	$ 214,440	$ 207,629	$ 180,046
Amortization—deferred financing costs	8,709	9,921	10,401
Debt modifications and extinguishments	25,173	1,503	192
Capitalized interest	(168,715)	(138,738)	(84,342)
Deferred interest	(281)	3,183	(3,318)
Interest income	(24,129)	(19,456)	(12,139)
Other, net	33,401	31,862	27,420
Interest and other financing costs, net	$ 88,598	$ 95,904	$ 118,260

Debt - Interest and Financing C

Debt - Interest and Financing Costs, Net (Narrative) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Debt Disclosure [Abstract]
Cash payments for interest	$ 194,800	$ 213,400	$ 170,100
Capitalized interest	$ 168,715	$ 138,738	$ 84,342

Derivative Financial Instrume_3

Derivative Financial Instruments - Schedule of Oil Derivative Contracts (Details) - Dated Brent	12 Months Ended
	Dec. 31, 2024 $ / bbl MBbls
Term January 2025 To June 2025 | Two-way collars
Derivative Financial Instruments
Volume (mbbls) | MBbls	2,000
Weighted Average Price per Bbl
Net deferred premium payable/(receivable) (usd per bbl)	0.50
Swap (usd per bbl)	0
Sold put (usd per bbl)	0
Floor (usd per bbl)	70
Ceiling (usd per bbl)	85
Term January 2025 To June 2025 | Swap
Derivative Financial Instruments
Volume (mbbls) | MBbls	2,000
Weighted Average Price per Bbl
Net deferred premium payable/(receivable) (usd per bbl)	0
Swap (usd per bbl)	75.48
Sold put (usd per bbl)	0
Floor (usd per bbl)	0
Ceiling (usd per bbl)	0
Term January 2025 To December 2025 | Two-way collars
Derivative Financial Instruments
Volume (mbbls) | MBbls	2,000
Weighted Average Price per Bbl
Net deferred premium payable/(receivable) (usd per bbl)	1
Swap (usd per bbl)	0
Sold put (usd per bbl)	0
Floor (usd per bbl)	70
Ceiling (usd per bbl)	85

Derivative Financial Instrume_4

Derivative Financial Instruments - Narrative (Details) - Dated Brent - Term January 2025 To December 2025 - Three-way Collars - Subsequent Event	1 Months Ended
	Jan. 31, 2025 $ / bbl MBbls
Derivative Financial Instruments
Volume (mbbls) | MBbls	2,000
Sold put (usd per bbl)	55
Floor (usd per bbl)	70
Ceiling (usd per bbl)	85

Derivative Financial Instrume_5

Derivative Financial Instruments - Schedule of Interest Rate Swaps (Details) - Term January 2025 To December 2025 - Swap $ in Thousands	Dec. 31, 2024 USD ($)
Derivative Financial Instruments
Notional	$ 500
Weighted average, fixed rate (as a percent)	3.645%

Derivative Financial Instrume_6

Derivative Financial Instruments - Schedule of Derivative Instruments and Gain/(Loss) from Derivatives (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Dec. 31, 2023
Derivative instruments, Balance Sheet Location
Derivatives assets—current	$ 8,916	$ 8,346
Derivatives assets—long-term	512	1,594
Derivatives liabilities—current	0	(3,103)
Not designated as hedging instruments
Derivative instruments, Balance Sheet Location
Total derivatives not designated as hedging instruments	11,670	6,765
Commodity | Not designated as hedging instruments
Derivative instruments, Balance Sheet Location
Derivatives assets—current	6,714	8,346
Derivatives assets—long-term	512	1,594
Derivatives liabilities—current	0	(3,103)
Provisional oil sales | Not designated as hedging instruments
Derivative instruments, Balance Sheet Location
Derivatives assets—current	2,242	0
Derivatives liabilities—current	0	(72)
Interest rate | Not designated as hedging instruments
Derivative instruments, Balance Sheet Location
Derivatives assets—current	$ 2,202	$ 0

Derivative Financial Instrume_7

Derivative Financial Instruments - Schedule of Location of Gain (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Derivative instruments, Location of Gain/(Loss)
Total derivatives not designated as hedging instruments	$ (14,747)	$ (28,349)	$ (275,465)
Provisional oil sales | Oil and gas revenue
Derivative instruments, Location of Gain/(Loss)
Total derivatives not designated as hedging instruments	(4,850)	(17,221)	(14,573)
Commodity | Derivatives, net
Derivative instruments, Location of Gain/(Loss)
Total derivatives not designated as hedging instruments	(12,099)	(11,128)	(260,892)
Interest rate | Interest expense
Derivative instruments, Location of Gain/(Loss)
Total derivatives not designated as hedging instruments	$ 2,202	$ 0	$ 0

Fair Value Measurements - Sched

Fair Value Measurements - Schedule of Company's Assets and Liabilities (Details) - Recurring basis - USD ($) $ in Thousands	Dec. 31, 2024	Dec. 31, 2023
Liabilities:
Total derivatives not designated as hedging instruments	$ 22,323	$ 6,765
Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Total derivatives not designated as hedging instruments	0	0
Significant Other Observable Inputs (Level 2)
Liabilities:
Total derivatives not designated as hedging instruments	22,323	6,765
Significant Unobservable Inputs (Level 3)
Liabilities:
Total derivatives not designated as hedging instruments	0	0
Commodity derivatives
Assets:
Derivative asset, fair value	7,226	9,940
Liabilities:
Derivative liability, fair value		(3,103)
Commodity derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivative asset, fair value	0	0
Liabilities:
Derivative liability, fair value		0
Commodity derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivative asset, fair value	7,226	9,940
Liabilities:
Derivative liability, fair value		(3,103)
Commodity derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivative asset, fair value	0	0
Liabilities:
Derivative liability, fair value		0
Provisional oil sales
Assets:
Derivative asset, fair value	2,242
Liabilities:
Derivative liability, fair value		(72)
Provisional oil sales | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivative asset, fair value	0
Liabilities:
Derivative liability, fair value		0
Provisional oil sales | Significant Other Observable Inputs (Level 2)
Assets:
Derivative asset, fair value	2,242
Liabilities:
Derivative liability, fair value		(72)
Provisional oil sales | Significant Unobservable Inputs (Level 3)
Assets:
Derivative asset, fair value	0
Liabilities:
Derivative liability, fair value		$ 0
Interest rate derivatives
Assets:
Derivative asset, fair value	2,202
Interest rate derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivative asset, fair value	0
Interest rate derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivative asset, fair value	2,202
Interest rate derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivative asset, fair value	0
Debt securities
Assets:
Derivative asset, fair value	10,653
Debt securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivative asset, fair value	0
Debt securities | Significant Other Observable Inputs (Level 2)
Assets:
Derivative asset, fair value	10,653
Debt securities | Significant Unobservable Inputs (Level 3)
Assets:
Derivative asset, fair value	$ 0

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Sep. 30, 2024	Mar. 31, 2024	Oct. 31, 2021	Mar. 31, 2021	Apr. 30, 2019
Fair Value Measurements
Decommissioning trust fund	$ 11,500,000
Impairment of long-lived assets	$ 0	$ 222,278,000	$ 449,969,000
Nonrecurring
Fair Value Measurements
Proved oil and gas reserves, fair value		$ 0	235,700,000
Nonrecurring | Measurement Input, Discount Rate | Valuation Technique, Discounted Cash Flow
Fair Value Measurements
Long-lived assets, measurement input		0.10
TEN Fields
Fair Value Measurements
Impairment of long-lived assets		$ 222,300,000	$ 450,000,000
7.125% Senior Notes | Senior Notes
Fair Value Measurements
Interest rate (as a percent)	7.125%							7.125%
7.750% Senior Notes | Senior Notes
Fair Value Measurements
Interest rate (as a percent)	7.75%					7.75%
7.500% Senior Notes | Senior Notes
Fair Value Measurements
Interest rate (as a percent)	7.50%						7.50%
8.750% Senior Notes | Senior Notes
Fair Value Measurements
Interest rate (as a percent)	8.75%			8.75%
3.125% Convertible Senior Notes | Senior Notes
Fair Value Measurements
Interest rate (as a percent)	3.125%	3.125%			3.125%

Fair Value Measurements - Sch_2

Fair Value Measurements - Schedule of Investments in Debt Securities Held by Decommissioning Trust Fund (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Fair Value Measurements
Cost	$ 0	$ 0
Purchases	11,460	0
Net Proceeds	101	0
Unrealized Gain (Loss)	(55)	0
Total	11,506	0
Debt securities
Fair Value Measurements
Cost	0	0
Purchases	10,708	0
Net Proceeds	0	0
Unrealized Gain (Loss)	(55)	0
Total	10,653	0
Cash and cash equivalents
Fair Value Measurements
Cost	0	0
Purchases	752	0
Net Proceeds	101	0
Unrealized Gain (Loss)	0	0
Total	$ 853	$ 0

Fair Value Measurements - Sch_3

Fair Value Measurements - Schedule of Costs and Fair Values of Investments in Debt Securities Held in Decommissioning Trust Fund (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Dec. 31, 2023
Cost
Less than 5 years	$ 10,708	$ 0
5 years to 10 years	0	0
Due after 10 years	0	0
Total	10,708	0
Estimated Fair Value
Less than 5 years	10,653	0
5 years to 10 years	0	0
Due after 10 years	0	0
Total	$ 10,653	$ 0

Fair Value Measurements - Sch_4

Fair Value Measurements - Schedule of Carrying Values and Fair Values of Financial Instruments (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Sep. 30, 2024	Mar. 31, 2024	Dec. 31, 2023	Oct. 31, 2021	Mar. 31, 2021	Apr. 30, 2019
Carrying Value
Fair Value Measurements
Long-term debt	$ 2,781,497			$ 2,414,921
Fair Value
Fair Value Measurements
Long-term debt	$ 2,669,653			2,335,049
7.125% Senior Notes | Senior Notes
Fair Value Measurements
Interest rate (as a percent)	7.125%						7.125%
7.125% Senior Notes | Senior Notes | Carrying Value
Fair Value Measurements
Long-term debt	$ 249,315			646,912
7.125% Senior Notes | Senior Notes | Fair Value
Fair Value Measurements
Long-term debt	$ 246,565			622,824
7.750% Senior Notes | Senior Notes
Fair Value Measurements
Interest rate (as a percent)	7.75%				7.75%
7.750% Senior Notes | Senior Notes | Carrying Value
Fair Value Measurements
Long-term debt	$ 347,910			396,718
7.750% Senior Notes | Senior Notes | Fair Value
Fair Value Measurements
Long-term debt	$ 339,927			374,764
7.500% Senior Notes | Senior Notes
Fair Value Measurements
Interest rate (as a percent)	7.50%					7.50%
7.500% Senior Notes | Senior Notes | Carrying Value
Fair Value Measurements
Long-term debt	$ 397,672			446,291
7.500% Senior Notes | Senior Notes | Fair Value
Fair Value Measurements
Long-term debt	$ 379,404			412,461
8.750% Senior Notes | Senior Notes
Fair Value Measurements
Interest rate (as a percent)	8.75%	8.75%
8.750% Senior Notes | Senior Notes | Carrying Value
Fair Value Measurements
Long-term debt	$ 494,997			0
8.750% Senior Notes | Senior Notes | Fair Value
Fair Value Measurements
Long-term debt	$ 470,965			$ 0
3.125% Convertible Senior Notes | Senior Notes
Fair Value Measurements
Interest rate (as a percent)	3.125%		3.125%	3.125%
3.125% Convertible Senior Notes | Senior Notes | Carrying Value
Fair Value Measurements
Long-term debt	$ 391,603			$ 0
3.125% Convertible Senior Notes | Senior Notes | Fair Value
Fair Value Measurements
Long-term debt	332,792			0
Facility | Revolving Credit Facility | Carrying Value
Fair Value Measurements
Long-term debt	900,000			925,000
Facility | Revolving Credit Facility | Fair Value
Fair Value Measurements
Long-term debt	$ 900,000			$ 925,000

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Asset retirement obligations:
Beginning asset retirement obligations	$ 346,786	$ 302,534
Liabilities incurred during period	23,104	16,196
Liabilities settled during period	(1,675)	(13,082)
Revisions in estimated retirement obligations	4,953	11,527
Accretion expense	33,843	29,611
Ending asset retirement obligations	$ 407,011	$ 346,786

Equity-based Compensation - Nar

Equity-based Compensation - Narrative (Details) - LTIP - USD ($) $ / shares in Units, shares in Millions	1 Months Ended		12 Months Ended
	Jan. 31, 2025	Jun. 30, 2023	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Equity-based Compensation
Additional shares authorized (in shares)		17
Number of shares authorized (in shares)			78.5
Number of shares remaining available for grant (in shares)			10.4
Vesting period			3 years
Restricted Stock Units (RSUs)
Equity-based Compensation
Compensation expense not yet recognized			$ 27,600,000
Weighted average period over which compensation expense is to be recognized (in years)			1 year 8 months 12 days
Restricted Stock Units (RSUs) | Subsequent Event
Equity-based Compensation
Compensation expense not yet recognized	$ 23,800,000
Weighted average period over which compensation expense is to be recognized (in years)	3 years
Market / Service Vesting Restricted Stock Units
Equity-based Compensation
Grant date fair value of awards granted (in dollars per share)			$ 8.58	$ 12.26	$ 6.98
Market / Service Vesting Restricted Stock Units | Subsequent Event
Equity-based Compensation
Granted (in shares)	3
Market / Service Vesting Restricted Stock Units | Maximum
Equity-based Compensation
Vesting percentage of the awards granted (as a percent)			200%
Grant date fair value of awards granted (in dollars per share)			$ 13.06
Expected volatility (as a percent)			105%
Risk-free interest rate (as a percent)			4.10%
Expected quarterly dividends (in dollars per share)			$ 0.05
Market / Service Vesting Restricted Stock Units | Minimum
Equity-based Compensation
Vesting percentage of the awards granted (as a percent)			0%
Grant date fair value of awards granted (in dollars per share)			$ 1.06
Expected volatility (as a percent)			50%
Risk-free interest rate (as a percent)			0.20%
Expected quarterly dividends (in dollars per share)			$ 0
Service Vesting Restricted Stock Units
Equity-based Compensation
Grant date fair value of awards granted (in dollars per share)			$ 6.22	$ 7.61	$ 4.70
Service Vesting Restricted Stock Units | Subsequent Event
Equity-based Compensation
Granted (in shares)	2.4

Equity-based Compensation - Sch

Equity-based Compensation - Schedule of Awards (Details) - LTIP - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Service Vesting Restricted Stock Units
Market / Service Vesting Restricted Stock Units
Outstanding at the beginning of the period (in shares)	4,710	4,916	4,696
Granted (in shares)	4,481	2,809	2,820
Forfeited (in shares)	(386)	(240)	(147)
Vested (in shares)	(4,052)	(2,775)	(2,453)
Outstanding at the end of the period (in shares)	4,753	4,710	4,916
Weighted-Average Grant-Date Fair Value
Outstanding at beginning of the period (in dollars per share)	$ 5.77	$ 4.18	$ 3.88
Granted (in dollars per share)	6.22	7.61	4.70
Forfeited (in dollars per share)	6.31	5.65	3.92
Vested (in dollars per share)	3.02	3.86	4.21
Outstanding at the end of the period (in dollars per share)	$ 6.36	$ 5.77	$ 4.18
Market / Service Vesting Restricted Stock Units
Market / Service Vesting Restricted Stock Units
Outstanding at the beginning of the period (in shares)	12,370	12,041	11,233
Granted (in shares)	6,232	3,482	3,388
Forfeited (in shares)	(485)	(203)	(389)
Vested (in shares)	(9,351)	(2,950)	(2,191)
Outstanding at the end of the period (in shares)	8,766	12,370	12,041
Weighted-Average Grant-Date Fair Value
Outstanding at beginning of the period (in dollars per share)	$ 6.59	$ 5.61	$ 5.28
Granted (in dollars per share)	8.58	12.26	6.98
Forfeited (in dollars per share)	9.57	8.17	6.21
Vested (in dollars per share)	3.91	8.22	5.98
Outstanding at the end of the period (in dollars per share)	9.07	$ 6.59	$ 5.61
Market / Service Vesting Restricted Stock Units | Minimum
Weighted-Average Grant-Date Fair Value
Granted (in dollars per share)	$ 1.06
Vesting percentage of the awards granted (as a percent)	0%
Market / Service Vesting Restricted Stock Units | Maximum
Weighted-Average Grant-Date Fair Value
Granted (in dollars per share)	$ 13.06
Vesting percentage of the awards granted (as a percent)	200%
Percent threshold target for grants and forfeitures (as a percent)	100%

Equity-based Compensation - S_2

Equity-based Compensation - Schedule of Share-based Payment Arrangement, Activity (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Equity-based Compensation
Net tax shortfall (windfall)	$ (11,615)	$ (3,201)	$ 673
LTIP
Equity-based Compensation
Share-based compensation expense	37,951	42,693	34,546
Total tax benefit	6,184	7,482	5,933
Net tax shortfall (windfall)	(9,562)	(3,201)	673
Fair value of awards vested	$ 82,317	$ 45,098	$ 22,205

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Income Taxes
Decrease in deferred tax liability	$ 52,100,000	$ 107,600,000	$ 242,700,000
Impairment of long-lived assets	$ 0	222,278,000	449,969,000
Deferred tax liability		77,800,000	157,600,000
Decrease from other reconciling items		$ 29,800,000
Decrease from pre-emption transaction			$ 44,600,000
Effective tax rate	46%	43%	33%
Change in valuation allowance	$ 72,179,000	$ 26,426,000	$ 11,391,000
Foreign net operating loss carryforwards	$ 128,600,000
United States
Income Taxes
Effective tax rate	(100.00%)	(2.00%)	10%
Change in valuation allowance	$ 33,100,000	$ 12,100,000	$ (12,300,000)
Foreign net operating loss carryforwards not expiring	$ 461,600,000
Ghana
Income Taxes
Effective tax rate	35%	36%
Equatorial Guinea
Income Taxes
Effective tax rate	(68.00%)	35%	36%
Foreign
Income Taxes
Effective tax rate	0%
Federal statutory income tax rate (as a percent)	0%
Foreign net operating loss carryforwards expiring	$ 70,700,000
Foreign net operating loss carryforwards not expiring	$ 58,000,000
Tullow
Income Taxes
Decrease from other reconciling items			$ 40,500,000
TEN Fields
Income Taxes
Impairment of long-lived assets		$ 222,300,000	$ 450,000,000

Income Taxes - Schedule of Comp

Income Taxes - Schedule of Components of Income (Loss) Before Income Taxes (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Income Taxes
Income before income taxes	$ 349,812	$ 371,735	$ 337,067
United States
Income Taxes
Income before income taxes	(162,243)	(88,458)	73,529
Foreign
Income Taxes
Income before income taxes	$ 512,055	$ 460,193	$ 263,538

Income Taxes - Schedule of Co_2

Income Taxes - Schedule of Components of Provision for Income Taxes Attributable to Income (Loss) Before Income Taxes (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Income Taxes
Current	$ 212,135	$ 265,775	$ 308,003
Deferred	(52,174)	(107,560)	(197,487)
Total tax expense (benefit)	159,961	158,215	110,516
United States
Income Taxes
Current	(1,074)	865	7,174
Deferred	2,933	551	84
Foreign
Income Taxes
Current	213,209	264,910	300,829
Deferred	$ (55,107)	$ (108,111)	$ (197,571)

Income Taxes - Schedule of Inco

Income Taxes - Schedule of Income Tax Expense (Benefit) and Reported Effective Tax Rate (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Reconciliation of income tax expense and the reported effective tax rate
Tax at statutory rate	$ 72,167	$ 78,064	$ 70,784
Foreign income (loss) taxed at different rates	66,634	48,768	20,663
Non-deductible compensation	8,813	5,915	3,012
Non-deductible and other items	7,216	2,243	3,993
Tax shortfall (windfall) on equity-based compensation, net	(11,615)	(3,201)	673
Change in valuation allowance	72,179	26,426	11,391
Change in statutory tax rate	(55,433)	0	0
Total tax expense (benefit)	$ 159,961	$ 158,215	$ 110,516
Effective tax rate	46%	43%	33%
Impact of (gains) losses incurred in jurisdictions in which the company is not subject to taxes on effective tax rate	$ 155,300	$ (4,000)	$ 21,000

Income Taxes - Schedule of Defe

Income Taxes - Schedule of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Dec. 31, 2023
Deferred tax assets:
Foreign capitalized operating expenses	$ 247,306	$ 209,453
Foreign net operating losses	34,764	14,458
United States net operating losses	96,945	78,706
United States deferred interest expense	69,051	43,411
Equity compensation	11,164	10,867
Asset retirement obligation and other	98,056	78,024
Total deferred tax assets	557,286	434,919
Valuation allowance	(405,831)	(333,651)
Total deferred tax assets, net	151,455	101,268
Deferred tax liabilities:
Depletion, depreciation and amortization related to property and equipment	(411,234)	(420,066)
Other deferred tax liabilities	(48,937)	(42,087)
Total deferred tax liabilities	(460,171)	(462,153)
Net deferred tax liability	$ (308,716)	$ (360,885)

Net Income (Loss) Per Share (De

Net Income (Loss) Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Numerator:
Net income allocable to common stockholders	$ 189,851	$ 213,520	$ 226,551
Weighted average number of shares outstanding:
Basic (in shares)	470,844	459,641	455,346
Restricted stock units (in shares)	5,847	21,429	19,511
Diluted (in shares)	476,691	481,070	474,857
Net income per share:
Basic (in dollars per share)	$ 0.40	$ 0.46	$ 0.50
Diluted (in dollars per share)	$ 0.40	$ 0.44	$ 0.48
Outstanding restricted stock units excluded from the computations of diluted net income per share (in shares)	3,300	0	100

Commitments and Contingencies (

Commitments and Contingencies (Details) $ in Millions	1 Months Ended	12 Months Ended
	Feb. 28, 2019 agreement	Dec. 31, 2024 USD ($) well	Dec. 31, 2023 USD ($)
Commitments and contingencies
Estimated decommissioning costs		$ 137.5
Commitments estimated period		12 years
National Oil Companies of Mauritania And Senegal | Carry Advance Agreements
Commitments and contingencies
Number of agreements | agreement	2
Share of development costs to be financed, up to		$ 370
Long-term receivables		$ 280.1	$ 259.2
Equatorial Guinea
Commitments and contingencies
Number of development wells | well		1
Gulf of America | Bureau Of Ocean Energy Management and Other Third Parties | Surety Bond
Commitments and contingencies
Required performance bonds		$ 169.4	$ 194.1

Additional Financial Informat_3

Additional Financial Information - Schedule of Accrued Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Dec. 31, 2023
Accrued liabilities:
Exploration, development and production	$ 78,163	$ 90,054
Revenue payable	18,909	20,506
Current asset retirement obligations	125	2,808
General and administrative expenses	39,071	29,766
Interest	47,228	36,410
Income taxes	52,262	111,212
Taxes other than income	1,222	1,029
Derivatives	844	1,372
Other	7,130	9,658
Accrued liabilities	$ 244,954	$ 302,815

Additional Financial Informat_4

Additional Financial Information - Schedule of Other Expenses, Net (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Additional Financial Information
Loss on disposal of inventory	$ 1,835	$ 7,372	$ 1,521
Gain on insurance settlements	0	0	(7,000)
(Gain) loss on asset retirement obligations liability settlements	(3,169)	6,034	(3,278)
Other, net	19,037	10,250	(297)
Other expenses, net	$ 17,703	$ 23,656	$ (9,054)

Business Segment Information -

Business Segment Information - Narrative (Details)	12 Months Ended
	Dec. 31, 2024 segment
Segment Reporting [Abstract]
Number of reportable segments	4

Business Segment Information _2

Business Segment Information - Financial Information (Details) - USD ($)	1 Months Ended		12 Months Ended
	Jun. 30, 2022	Mar. 31, 2022	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Segment Reporting Information [Line Items]
Oil and gas revenue			$ 1,675,358,000	$ 1,701,608,000	$ 2,245,355,000
Gain on sale of assets			0	0	50,471,000
Other income, net			204,000	(73,000)	3,949,000
Total revenues and other income			1,675,562,000	1,701,535,000	2,299,775,000
Oil and gas production			530,514,000	390,097,000	409,299,000
Exploration expenses			119,907,000	42,278,000	134,230,000
General and administrative			100,155,000	99,532,000	100,856,000
Depletion, depreciation and amortization			456,774,000	444,927,000	498,256,000
Impairment of long-lived assets			0	222,278,000	449,969,000
Interest and other financing costs, net			88,598,000	95,904,000	118,260,000
Derivatives, net			12,099,000	11,128,000	260,892,000
Other expenses, net			17,703,000	23,656,000	(9,054,000)
Total costs and expenses			1,325,750,000	1,329,800,000	1,962,708,000
Income (loss) before income taxes			349,812,000	371,735,000	337,067,000
Income tax expense (benefit)			159,961,000	158,215,000	110,516,000
Net income (loss)			189,851,000	213,520,000	226,551,000
Consolidated capital expenditures			828,813,000	849,999,000	611,588,000
Property and equipment, net			4,444,221,000	4,160,229,000	3,842,647,000
Total assets			5,308,988,000	4,938,134,000	4,579,988,000
Proceeds on sale of assets			0	0	168,703,000
Tullow | Jubilee Unit Area And Ten Fields
Segment Reporting Information [Line Items]
Proceeds on sale of assets		$ 118,200,000			118,200,000
Marubeni | Kodiak Field
Segment Reporting Information [Line Items]
Total purchase price	$ 29,000,000				29,000,000
Corporate & Other
Segment Reporting Information [Line Items]
Oil and gas revenue			0	0	0
Gain on sale of assets					50,000,000
Other income, net			171,706,000	157,770,000	386,002,000
Total revenues and other income			171,706,000	157,770,000	436,002,000
Oil and gas production			0	0	0
Exploration expenses			4,906,000	5,757,000	6,576,000
General and administrative			212,354,000	199,283,000	180,594,000
Depletion, depreciation and amortization			2,077,000	1,780,000	1,614,000
Impairment of long-lived assets				0	0
Interest and other financing costs, net			199,552,000	155,319,000	114,598,000
Derivatives, net			12,099,000	11,128,000	260,892,000
Other expenses, net			35,000	5,110,000	496,000
Total costs and expenses			431,023,000	378,377,000	564,770,000
Income (loss) before income taxes			(259,317,000)	(220,607,000)	(128,768,000)
Income tax expense (benefit)			(14,007,000)	(13,798,000)	10,621,000
Net income (loss)			(245,310,000)	(206,809,000)	(139,389,000)
Consolidated capital expenditures			6,529,000	9,662,000	(41,986,000)
Property and equipment, net			16,507,000	18,041,000	16,847,000
Total assets			25,867,010,000	21,599,662,000	19,554,236,000
Eliminations
Segment Reporting Information [Line Items]
Oil and gas revenue			0	0	0
Gain on sale of assets					0
Other income, net			(174,445,000)	(160,777,000)	(388,236,000)
Total revenues and other income			(174,445,000)	(160,777,000)	(388,236,000)
Oil and gas production			0	0	0
Exploration expenses			0	0	0
General and administrative			(162,346,000)	(149,649,000)	(127,343,000)
Depletion, depreciation and amortization			0	0	0
Impairment of long-lived assets					0
Interest and other financing costs, net			0	0	0
Derivatives, net			0	0	0
Other expenses, net			(12,099,000)	(11,128,000)	(260,893,000)
Total costs and expenses			(174,445,000)	(160,777,000)	(388,236,000)
Income (loss) before income taxes			0	0	0
Income tax expense (benefit)			0	0	0
Net income (loss)			0	0	0
Consolidated capital expenditures			0	0	0
Property and equipment, net			0	0	0
Total assets			(33,836,554,000)	(28,462,797,000)	(25,046,118,000)
Ghana | Operating Segments
Segment Reporting Information [Line Items]
Oil and gas revenue			1,044,562,000	1,062,482,000	1,350,962,000
Gain on sale of assets					0
Other income, net			48,000	(403,000)	428,000
Total revenues and other income			1,044,610,000	1,062,079,000	1,351,390,000
Oil and gas production			164,385,000	175,265,000	212,729,000
Exploration expenses			3,572,000	872,000	14,987,000
General and administrative			13,718,000	12,913,000	15,310,000
Depletion, depreciation and amortization			203,501,000	240,998,000	289,058,000
Impairment of long-lived assets				222,278,000	450,357,000
Interest and other financing costs, net			51,302,000	56,988,000	64,620,000
Derivatives, net			0	0	0
Other expenses, net			14,894,000	7,963,000	233,785,000
Total costs and expenses			451,372,000	717,277,000	1,280,846,000
Income (loss) before income taxes			593,238,000	344,802,000	70,544,000
Income tax expense (benefit)			201,006,000	122,704,000	28,091,000
Net income (loss)			392,232,000	222,098,000	42,453,000
Consolidated capital expenditures			139,130,000	276,849,000	98,540,000
Property and equipment, net			986,693,000	1,036,651,000	1,202,937,000
Total assets			3,682,493,000	3,252,235,000	2,886,242,000
Equatorial Guinea | Operating Segments
Segment Reporting Information [Line Items]
Oil and gas revenue			260,675,000	267,494,000	346,783,000
Gain on sale of assets					0
Other income, net			0	10,000	3,350,000
Total revenues and other income			260,675,000	267,504,000	350,133,000
Oil and gas production			136,398,000	114,411,000	90,602,000
Exploration expenses			73,009,000	7,915,000	7,378,000
General and administrative			6,129,000	5,555,000	6,703,000
Depletion, depreciation and amortization			65,178,000	51,750,000	53,765,000
Impairment of long-lived assets				0	0
Interest and other financing costs, net			(2,697,000)	(2,942,000)	(2,494,000)
Derivatives, net			0	0	0
Other expenses, net			(4,673,000)	3,208,000	8,397,000
Total costs and expenses			273,344,000	179,897,000	164,351,000
Income (loss) before income taxes			(12,669,000)	87,607,000	185,782,000
Income tax expense (benefit)			(41,217,000)	35,666,000	72,814,000
Net income (loss)			28,548,000	51,941,000	112,968,000
Consolidated capital expenditures			177,196,000	74,573,000	36,036,000
Property and equipment, net			482,223,000	424,030,000	396,737,000
Total assets			2,313,856,000	1,918,131,000	1,463,211,000
Mauritania / Senegal | Operating Segments
Segment Reporting Information [Line Items]
Oil and gas revenue			0	0	0
Gain on sale of assets					0
Other income, net			0	0	0
Total revenues and other income			0	0	0
Oil and gas production			93,412,000	0	0
Exploration expenses			16,973,000	15,784,000	82,526,000
General and administrative			10,974,000	9,354,000	9,798,000
Depletion, depreciation and amortization			950,000	917,000	412,000
Impairment of long-lived assets				0	0
Interest and other financing costs, net			(146,952,000)	(119,697,000)	(69,644,000)
Derivatives, net			0	0	0
Other expenses, net			14,764,000	7,997,000	(1,178,000)
Total costs and expenses			(9,879,000)	(85,645,000)	21,914,000
Income (loss) before income taxes			9,879,000	85,645,000	(21,914,000)
Income tax expense (benefit)			0	0	0
Net income (loss)			9,879,000	85,645,000	(21,914,000)
Consolidated capital expenditures			324,798,000	276,484,000	407,982,000
Property and equipment, net			2,057,786,000	1,788,214,000	1,396,884,000
Total assets			3,188,067,000	2,642,098,000	2,026,776,000
Gulf of America | Operating Segments
Segment Reporting Information [Line Items]
Oil and gas revenue			370,121,000	371,632,000	547,610,000
Gain on sale of assets					471,000
Other income, net			2,895,000	3,327,000	2,405,000
Total revenues and other income			373,016,000	374,959,000	550,486,000
Oil and gas production			136,319,000	100,421,000	105,968,000
Exploration expenses			21,447,000	11,950,000	22,763,000
General and administrative			19,326,000	22,076,000	15,794,000
Depletion, depreciation and amortization			185,068,000	149,482,000	153,407,000
Impairment of long-lived assets				0	(388,000)
Interest and other financing costs, net			(12,607,000)	6,236,000	11,180,000
Derivatives, net			0	0	0
Other expenses, net			4,782,000	10,506,000	10,339,000
Total costs and expenses			354,335,000	300,671,000	319,063,000
Income (loss) before income taxes			18,681,000	74,288,000	231,423,000
Income tax expense (benefit)			14,179,000	13,643,000	(1,010,000)
Net income (loss)			4,502,000	60,645,000	232,433,000
Consolidated capital expenditures			181,160,000	212,431,000	111,016,000
Property and equipment, net			901,012,000	893,293,000	829,242,000
Total assets			$ 4,094,116,000	$ 3,988,805,000	$ 3,695,641,000

Business Segment Information _3

Business Segment Information - Consolidated Capital Expenditures (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Segment Reporting [Abstract]
Oil and gas assets	$ 933,659	$ 932,603	$ 787,297
Acquisition of oil and gas properties	0	0	22,078
Proceeds on sale of assets	0	0	(168,703)
Changes in capital accruals	13,392	6,732	396
Exploration expense, excluding unsuccessful well costs and leasehold impairments	45,418	40,070	47,289
Capitalized interest	(168,715)	(138,738)	(84,343)
Other	5,059	9,332	7,574
Total consolidated capital expenditures	$ 828,813	$ 849,999	$ 611,588

Condensed Parent Company Fina_2

Condensed Parent Company Financial Statements - Balance Sheet (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 84,972	$ 95,345	$ 183,405
Prepaid expenses and other	16,414	46,235
Total current assets	446,132	422,713
Restricted cash	305	3,416	3,416
Long-term deferred tax asset	4,717	3,033
Total assets	5,308,988	4,938,134	4,579,988
Current liabilities:
Accounts payable	349,994	248,912
Accrued liabilities	244,954	302,815
Total current liabilities	594,948	554,830
Long-term debt, net	2,744,712	2,390,914
Stockholders’ equity:
Preference shares, $0.01 par value; 200,000,000 authorized shares; zero issued at December 31, 2024 and December 31, 2023	0	0
Common stock, $0.01 par value; 2,000,000,000 authorized shares; 516,158,749 and 504,392,980 issued at December 31, 2024 and December 31, 2023, respectively	5,162	5,044
Additional paid-in capital	2,514,739	2,536,621
Accumulated deficit	(1,082,470)	(1,272,321)
Treasury stock, at cost, 44,263,269 shares at December 31, 2024 and 2023, respectively	(237,007)	(237,007)
Total stockholders’ equity	1,200,424	1,032,337	$ 787,848	$ 529,237
Total liabilities and stockholders’ equity	5,308,988	4,938,134
Parent Company
Current assets:
Cash and cash equivalents	39	275
Prepaid expenses and other	707	752
Total current assets	746	1,027
Investment in subsidiaries at equity	3,262,312	2,683,656
Deferred financing costs, net of accumulated amortization of $11,668 and $15,583 at December 31, 2024 and December 31, 2023, respectively	0	2,320
Restricted cash	305	305
Long-term deferred tax asset	22,919	12,050
Total assets	3,286,282	2,699,358
Current liabilities:
Accrued liabilities	34,845	27,650
Total current liabilities	210,790	180,341
Long-term debt, net	1,875,068	1,486,680
Stockholders’ equity:
Preference shares, $0.01 par value; 200,000,000 authorized shares; zero issued at December 31, 2024 and December 31, 2023	0	0
Common stock, $0.01 par value; 2,000,000,000 authorized shares; 516,158,749 and 504,392,980 issued at December 31, 2024 and December 31, 2023, respectively	5,162	5,044
Additional paid-in capital	2,514,739	2,536,621
Accumulated deficit	(1,082,470)	(1,272,321)
Treasury stock, at cost, 44,263,269 shares at December 31, 2024 and 2023, respectively	(237,007)	(237,007)
Total stockholders’ equity	1,200,424	1,032,337
Total liabilities and stockholders’ equity	3,286,282	2,699,358
Parent Company | Nonrelated Party
Current liabilities:
Accounts payable	23	12
Parent Company | Related Party
Current liabilities:
Accounts payable	$ 175,922	$ 152,679

Condensed Parent Company Fina_3

Condensed Parent Company Financial Statements - Balance Sheet - Additional Information (Details) - USD ($) $ / shares in Units, $ in Thousands	Dec. 31, 2024	Dec. 31, 2023
Condensed Balance Sheet Statements, Captions [Line Items]
Preference shares, par value (in dollars per share)	$ 0.01	$ 0.01
Preference shares, authorized shares (in shares)	200,000,000	200,000,000
Preference shares, issued shares (in shares)	0	0
Common shares, par value (in dollars per share)	$ 0.01	$ 0.01
Common shares, authorized shares (in shares)	2,000,000,000	2,000,000,000
Common shares, issued shares (in shares)	516,158,749	504,392,980
Treasury stock shares (in shares)	44,263,269	44,263,269
Parent Company
Condensed Balance Sheet Statements, Captions [Line Items]
Deferred financing costs, accumulated amortization	$ 11,668	$ 15,583
Preference shares, par value (in dollars per share)	$ 0.01	$ 0.01
Preference shares, authorized shares (in shares)	200,000,000	200,000,000
Preference shares, issued shares (in shares)	0	0
Common shares, par value (in dollars per share)	$ 0.01	$ 0.01
Common shares, authorized shares (in shares)	2,000,000,000	2,000,000,000
Common shares, issued shares (in shares)	516,158,749	504,392,980
Treasury stock shares (in shares)	44,263,269	44,263,269

Condensed Parent Company Fina_4

Condensed Parent Company Financial Statements - Statement of Operations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Revenues and other income:
Oil and gas revenue	$ 1,675,358	$ 1,701,608	$ 2,245,355
Total revenues and other income	1,675,562	1,701,535	2,299,775
Costs and expenses:
General and administrative	100,155	99,532	100,856
Interest and other financing costs, net	88,598	95,904	118,260
Derivatives, net	12,099	11,128	260,892
Other expenses, net	17,703	23,656	(9,054)
Total costs and expenses	1,325,750	1,329,800	1,962,708
Income before income taxes	349,812	371,735	337,067
Income tax expense (benefit)	159,961	158,215	110,516
Net income (loss)	189,851	213,520	226,551
Parent Company
Revenues and other income:
Oil and gas revenue	0	0	0
Total revenues and other income	0	0	75,740
Costs and expenses:
Interest and other financing costs, net	136,950	122,773	123,247
Derivatives, net	0	0	75,740
Other expenses, net	65	131	17
Equity in (earnings) of subsidiaries	(365,362)	(370,729)	(415,546)
Total costs and expenses	(177,742)	(201,594)	(176,134)
Income before income taxes	177,742	201,594	251,874
Income tax expense (benefit)	(12,109)	(11,926)	25,323
Net income (loss)	189,851	213,520	226,551
Parent Company | Related Party
Revenues and other income:
Other income—related party	0	0	75,740
Costs and expenses:
General and administrative	1,326	(6,048)	(3,772)
Parent Company | Nonrelated Party
Costs and expenses:
General and administrative	$ 49,279	$ 52,279	$ 44,180

Condensed Parent Company Fina_5

Condensed Parent Company Financial Statements - Statements of Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Operating activities
Net income	$ 189,851	$ 213,520	$ 226,551
Adjustments to reconcile net income to net cash (used in) operating activities:
Equity-based compensation	37,951	42,693	34,546
Depreciation and amortization	465,483	454,848	508,657
Deferred income taxes	(52,174)	(107,560)	(197,487)
Other income—related party	(13,735)	5,709	(10,099)
Change in fair value of derivatives	14,747	28,349	275,465
Cash settlements on derivatives	(19,652)	(32,426)	(344,468)
Debt modifications and extinguishments	25,173	1,503	192
Changes in assets and liabilities:
Decrease in receivables	(63,331)	(16,223)	68,829
Increase (decrease) in accounts payable and accrued liabilities	14,459	(4,062)	82,555
Net cash provided by operating activities	678,249	765,170	1,130,476
Investing activities
Net cash used in investing activities	(966,056)	(994,850)	(703,855)
Financing activities
Repurchase of senior notes	(499,515)	0	0
Purchase of capped call transactions	(49,800)	0	0
Dividends	0	(166)	(655)
Other financing costs	(36,647)	(13,214)	(9,041)
Net cash provided by (used in) financing activities	274,323	141,620	(414,696)
Net increase (decrease) in cash, cash equivalents and restricted cash	(13,484)	(88,060)	11,925
Cash, cash equivalents and restricted cash at beginning of period	98,761	186,821	174,896
Cash, cash equivalents and restricted cash at end of period	85,277	98,761	186,821
Parent Company
Operating activities
Net income	189,851	213,520	226,551
Adjustments to reconcile net income to net cash (used in) operating activities:
Equity in (earnings) of subsidiaries	(365,362)	(370,729)	(415,546)
Equity-based compensation	37,951	42,693	34,546
Depreciation and amortization	7,497	6,588	6,359
Deferred income taxes	(10,869)	(11,589)	18,034
Change in fair value of derivatives	0	0	75,741
Cash settlements on derivatives	0	0	(70,327)
Debt modifications and extinguishments	3,192	0	192
Changes in assets and liabilities:
Decrease in receivables	6	87	306
(Increase) decrease in prepaid expenses and other	45	299	(94)
Decrease due to/from related party	22,501	37,765	33,214
Increase (decrease) in accounts payable and accrued liabilities	6,694	60	(4,159)
Net cash provided by operating activities	(108,494)	(80,893)	(99,536)
Investing activities
Investment in subsidiaries	(213,294)	90,858	104,676
Net cash used in investing activities	(213,294)	90,858	104,676
Financing activities
Net proceeds from issuance of senior notes	885,285	0	0
Repurchase of senior notes	(499,515)	0	0
Purchase of capped call transactions	(49,800)
Dividends	0	(166)	(655)
Other financing costs	(14,418)	(11,810)	(8,892)
Net cash provided by (used in) financing activities	321,552	(11,976)	(9,547)
Net increase (decrease) in cash, cash equivalents and restricted cash	(236)	(2,011)	(4,407)
Cash, cash equivalents and restricted cash at beginning of period	580	2,591	6,998
Cash, cash equivalents and restricted cash at end of period	344	580	2,591
Parent Company | Related Party
Adjustments to reconcile net income to net cash (used in) operating activities:
Other income—related party	$ 0	$ 413	$ (4,353)

Valuation and Qualifying Acco_2

Valuation and Qualifying Accounts (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Allowance for credit losses
Changes in valuation and qualifying Accounts
Balance at the beginning of the period	$ 9,847	$ 7,011	$ 5,189
Charged to Costs and Expenses	3,721	2,842	2,509
Charged To Other Accounts	0	(6)	(687)
Deductions From Reserves	0	0	0
Balance at the end of the period	13,568	9,847	7,011
Allowance for deferred tax assets
Changes in valuation and qualifying Accounts
Balance at the beginning of the period	333,651	312,727	318,343
Charged to Costs and Expenses	72,180	20,924	(5,616)
Charged To Other Accounts	0	0	0
Deductions From Reserves	0	0	0
Balance at the end of the period	$ 405,831	$ 333,651	$ 312,727