Kosmos Energy (KOS) 10-Q 7 Nov 22 2022 Q3 Quarterly report Financial data

Cover

Cover - shares	9 Months Ended
	Sep. 30, 2022	Nov. 03, 2022
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2022
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
Title of 12(b) Security	Common Stock $0.01 par value
Trading Symbol	KOS
Security Exchange Name	NYSE
City Area Code	214
Local Phone Number	445 9600
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		455,893,501
Entity Central Index Key	0001509991
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q3

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 231,565	$ 131,620
Restricted cash	27	42,971
Receivables:
Joint interest billings, net	40,643	36,908
Oil sales	67,604	134,004
Other	22,385	6,614
Inventories	150,284	165,247
Prepaid expenses and other	23,402	18,899
Derivatives	11,879	5,689
Total current assets	547,789	541,952
Property and equipment:
Oil and gas properties, net	4,132,962	4,177,323
Other property, net	5,705	6,664
Property and equipment, net	4,138,667	4,183,987
Other assets:
Restricted cash	305	305
Long-term receivables	201,196	191,150
Deferred financing costs, net of accumulated amortization of $12,683 and $19,912 at September 30, 2022 and December 31, 2021, respectively	5,220	1,090
Derivatives	8,646	1,026
Other	19,589	21,141
Total assets	4,921,412	4,940,651
Current liabilities:
Accounts payable	272,767	184,403
Accrued liabilities	252,196	250,670
Current maturities of long-term debt	30,000	30,000
Derivatives	37,477	65,879
Total current liabilities	592,440	530,952
Long-term liabilities:
Long-term debt, net	2,275,769	2,590,495
Derivatives	2,147	6,298
Asset retirement obligations	275,867	322,237
Deferred tax liabilities	629,755	711,038
Other long-term liabilities	251,943	250,394
Total long-term liabilities	3,435,481	3,880,462
Stockholders’ equity:
Preference shares, $0.01 par value; 200,000,000 authorized shares; zero issued at September 30, 2022 and December 31, 2021	0	0
Common stock, $0.01 par value; 2,000,000,000 authorized shares; 500,104,524 and 496,152,331 issued at September 30, 2022 and December 31, 2021, respectively	5,001	4,962
Additional paid-in capital	2,497,062	2,473,674
Accumulated deficit	(1,371,565)	(1,712,392)
Treasury stock, at cost, 44,263,269 shares at September 30, 2022 and December 31, 2021, respectively	(237,007)	(237,007)
Total stockholders’ equity	893,491	529,237
Total liabilities and stockholders’ equity	$ 4,921,412	$ 4,940,651

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Deferred financing costs, accumulated amortization	$ 12,683	$ 19,912
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)	500,104,524	496,152,331
Treasury stock shares (in shares)	44,263,269	44,263,269

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Revenues and other income:
Oil and gas revenue	$ 456,056			$ 198,936			$ 1,735,439	$ 759,455
Gain on sale of assets	0			1,538			471	1,564
Other income, net	48			66			143	210
Total revenues and other income	456,104			200,540			1,736,053	761,229
Costs and expenses:
Oil and gas production	62,372			50,316			277,264	211,871
Facilities insurance modifications, net	494			1,554			7,246	3,495
Exploration expenses	17,215			23,982			118,656	41,452
General and administrative	24,007			22,459			74,424	66,628
Depletion, depreciation and amortization	106,313			64,914			386,961	292,616
Interest and other financing costs, net	29,796			26,873			92,317	90,727
Derivatives, net	(113,842)			38,224			243,534	252,606
Other expenses, net	(218)			194			(1,320)	1,003
Total costs and expenses	126,137			228,516			1,199,082	960,398
Income (loss) before income taxes	329,967			(27,976)			536,971	(199,169)
Income tax expense (benefit)	107,713			621			196,144	(22,617)
Net income (loss)	$ 222,254	$ 117,173	$ 1,400	$ (28,597)	$ (57,187)	$ (90,768)	$ 340,827	$ (176,552)
Earnings Per Share [Abstract]
Basic (in dollars per share)	$ 0.49			$ (0.07)			$ 0.75	$ (0.43)
Diluted (in dollars per share)	$ 0.47			$ (0.07)			$ 0.72	$ (0.43)
Weighted average number of shares used to compute net income (loss) per share:
Basic (in shares)	455,840			408,520			455,158	408,009
Diluted (in shares)	476,431			408,520			474,820	408,009

CONSOLIDATED STATEMENTS OF STOC

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY - USD ($) shares in Thousands, $ in Thousands	Total	Common Shares	Additional Paid-in Capital	Accumulated Deficit	Treasury Stock
Balance at the beginning (in shares) at Dec. 31, 2020		449,718
Balance at the beginning at Dec. 31, 2020	$ 440,154	$ 4,497	$ 2,307,220	$ (1,634,556)	$ (237,007)
Increase (Decrease) in Shareholders' Equity
Dividends	90		90
Equity-based compensation	8,327		8,327
Restricted stock units (in shares)		2,408
Restricted stock units	0	$ 24	(24)
Tax withholdings on restricted stock units	(1,018)		(1,018)
Net income (loss)	(90,768)			(90,768)
Balance at the end (in shares) at Mar. 31, 2021		452,126
Balance at the end at Mar. 31, 2021	356,785	$ 4,521	2,314,595	(1,725,324)	(237,007)
Balance at the beginning (in shares) at Dec. 31, 2020		449,718
Balance at the beginning at Dec. 31, 2020	440,154	$ 4,497	2,307,220	(1,634,556)	(237,007)
Increase (Decrease) in Shareholders' Equity
Net income (loss)	(176,552)
Balance at the end (in shares) at Sep. 30, 2021		453,005
Balance at the end at Sep. 30, 2021	286,752	$ 4,530	2,330,337	(1,811,108)	(237,007)
Balance at the beginning (in shares) at Mar. 31, 2021		452,126
Balance at the beginning at Mar. 31, 2021	356,785	$ 4,521	2,314,595	(1,725,324)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends	29		29
Equity-based compensation	7,634		7,634
Restricted stock units (in shares)		540
Restricted stock units	0	$ 6	(6)
Tax withholdings on restricted stock units	(19)		(19)
Net income (loss)	(57,187)			(57,187)
Balance at the end (in shares) at Jun. 30, 2021		452,666
Balance at the end at Jun. 30, 2021	307,242	$ 4,527	2,322,233	(1,782,511)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends	21		21
Equity-based compensation	8,149		8,149
Restricted stock units (in shares)		339
Restricted stock units	0	$ 3	(3)
Tax withholdings on restricted stock units	(63)		(63)
Net income (loss)	(28,597)			(28,597)
Balance at the end (in shares) at Sep. 30, 2021		453,005
Balance at the end at Sep. 30, 2021	286,752	$ 4,530	2,330,337	(1,811,108)	(237,007)
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	12		12
Equity-based compensation	8,425		8,425
Restricted stock units (in shares)		3,377
Restricted stock units	0	$ 33	(33)
Tax withholdings on restricted stock units	(2,753)		(2,753)
Net income (loss)	1,400			1,400
Balance at the end (in shares) at Mar. 31, 2022		499,529
Balance at the end at Mar. 31, 2022	536,321	$ 4,995	2,479,325	(1,710,992)	(237,007)
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
Net income (loss)	340,827
Balance at the end (in shares) at Sep. 30, 2022		500,105
Balance at the end at Sep. 30, 2022	893,491	$ 5,001	2,497,062	(1,371,565)	(237,007)
Balance at the beginning (in shares) at Mar. 31, 2022		499,529
Balance at the beginning at Mar. 31, 2022	536,321	$ 4,995	2,479,325	(1,710,992)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends	(14)		(14)
Equity-based compensation	8,886		8,886
Restricted stock units (in shares)		487
Restricted stock units	0	$ 5	(5)
Net income (loss)	117,173			117,173
Balance at the end (in shares) at Jun. 30, 2022		500,016
Balance at the end at Jun. 30, 2022	662,366	$ 5,000	2,488,192	(1,593,819)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends	0		0
Equity-based compensation	8,871		8,871
Restricted stock units (in shares)		89
Restricted stock units	0	$ 1	(1)
Net income (loss)	222,254			222,254
Balance at the end (in shares) at Sep. 30, 2022		500,105
Balance at the end at Sep. 30, 2022	$ 893,491	$ 5,001	$ 2,497,062	$ (1,371,565)	$ (237,007)

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Operating activities
Net income (loss)	$ 340,827	$ (176,552)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depletion, depreciation and amortization (including deferred financing costs)	394,799	300,404
Deferred income taxes	(37,445)	(68,366)
Unsuccessful well costs and leasehold impairments	83,086	16,772
Change in fair value of derivatives	257,112	259,289
Cash settlements on derivatives, net (including $(289.9) million and $(142.9) million on commodity hedges during 2022 and 2021)	(304,328)	(150,255)
Equity-based compensation	25,896	24,011
Gain on sale of assets	(471)	(1,564)
Loss on extinguishment of debt	192	15,223
Other	(5,940)	(2,763)
Changes in assets and liabilities:
Decrease in receivables	54,035	1,537
Increase in inventories	(4,377)	(24,280)
Increase in prepaid expenses and other	(5,704)	(4,800)
Increase (decrease) in accounts payable	64,216	(35,545)
Increase (decrease) in accrued liabilities	1,338	(9,270)
Net cash provided by operating activities	863,236	143,841
Investing activities
Oil and gas assets	(543,349)	(377,850)
Acquisition of oil and gas properties	(21,205)	0
Proceeds on sale of assets	118,703	5,327
Notes receivable from partners	(28,188)	(41,712)
Net cash used in investing activities	(474,039)	(414,235)
Financing activities
Borrowings under long-term debt	0	250,000
Payments on long-term debt	(322,500)	(400,000)
Net proceeds from issuance of senior notes	0	444,375
Tax withholdings on restricted stock units	(2,753)	(1,100)
Dividends	(655)	(512)
Deferred financing costs	(6,288)	(17,291)
Net cash provided by (used in) financing activities	(332,196)	275,472
Net increase in cash, cash equivalents and restricted cash	57,001	5,078
Cash, cash equivalents and restricted cash at beginning of period	174,896	149,764
Cash, cash equivalents and restricted cash at end of period	231,897	154,842
Cash paid for:
Interest, net of capitalized interest	79,787	61,046
Income taxes, net of refund received	$ 195,782	$ 67,581

CONSOLIDATED STATEMENTS OF CA_2

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Statement of Cash Flows [Abstract]
Cash settlements on commodity hedges derivatives	$ (289.9)	$ (142.9)

Organization

Organization	9 Months Ended
	Sep. 30, 2022
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 is a full-cycle, deepwater, independent oil and gas exploration and production company focused along the Atlantic Margins. Our key assets include production offshore Ghana, Equatorial Guinea and the U.S. Gulf of Mexico, as well as a world-class gas development offshore Mauritania and Senegal. We also pursue a proven basin exploration program in Equatorial Guinea, Ghana and the U.S. Gulf of Mexico. 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 U.S. Gulf of Mexico.

Accounting Policies

Accounting Policies	9 Months Ended
	Sep. 30, 2022
Accounting Policies [Abstract]
Accounting Policies	Accounting Policies General The interim consolidated financial statements included in this report are unaudited and, in the opinion of management, include all adjustments of a normal recurring nature necessary for a fair presentation of the results for the interim periods. The results of the interim periods shown in this report are not necessarily indicative of the final results to be expected for the full year. The interim consolidated financial statements were prepared in accordance with the requirements of the SEC for interim reporting. As permitted under those rules, certain notes or other financial information that are normally required by GAAP have been condensed or omitted from these interim consolidated financial statements. These interim consolidated financial statements and the accompanying notes should be read in conjunction with our audited consolidated financial statements for the year ended December 31, 2021, included in our annual report on Form 10-K. Reclassifications Certain prior period amounts have been reclassified to conform with the current presentation. Such reclassifications had no significant impact on our reported net income (loss), current assets, total assets, current liabilities, total liabilities, stockholders’ equity or cash flows. Cash, Cash Equivalents and Restricted Cash September 30, December 31, (In thousands) Cash and cash equivalents $ 231,565 $ 131,620 Restricted cash - current 27 42,971 Restricted cash - long-term 305 305 Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 231,897 $ 174,896 Cash and cash equivalents include 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 and the 7.500% Senior Notes plus the Corporate Revolver or the Facility, whichever is greater. As of March 31, 2022 our net leverage ratio was below 2.50x, therefore in May 2022, we released $59.1 million from restricted cash upon submission of the net leverage test as of March 31, 2022. As of September 30, 2022 our net leverage ratio remained below 2.50x. Inventories Inventories consisted of $129.0 million and $149.5 million of materials and supplies and $21.3 million and $15.7 million of hydrocarbons as of September 30, 2022 and December 31, 2021, 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. During the third quarter of 2022, Kosmos sold $14.9 million of material and supplies inventory in exchange for cash. 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. Revenue Recognition 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 provisional price contracts which contain an embedded derivative that is required to be 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 embedded 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 after the sale. Oil and gas revenue is composed of the following: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (In thousands) Revenues from contract with customer - Equatorial Guinea $ 41,178 $ 34,247 $ 263,532 $ 145,378 Revenues from contract with customer - Ghana 301,855 65,969 1,044,039 321,855 Revenues from contract with customers - U.S. Gulf of Mexico 116,603 96,626 441,446 298,905 Provisional oil sales contracts (3,580) 2,094 (13,578) (6,683) Oil and gas revenue $ 456,056 $ 198,936 $ 1,735,439 $ 759,455 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 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 operations. The continued economic disruption and volatility in the global and industry-wide markets resulting from the COVID-19 pandemic, Russia’s invasion of Ukraine, a potential global recession, 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.

Acquisitions and Divestitures

Acquisitions and Divestitures	9 Months Ended
	Sep. 30, 2022
Business Combination and Asset Acquisition [Abstract]
Acquisitions and Divestitures	Acquisitions and DivestituresFollowing the closing of the acquisition of Anadarko WCTP Company (“Anadarko WCTP”) in the fourth quarter of 2021, Kosmos’ interest in the Jubilee Unit Area and the TEN fields offshore Ghana were 42.1% and 28.1%, respectively. 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”) and PetroSA that they intend to exercise their pre-emption rights in relation to Kosmos’ acquisition of Anadarko WCTP. After execution of definitive transaction documentation and receipt of governmental approvals, Kosmos concluded the pre-emption transaction with Tullow in March 2022. Following the completion of the pre-emption by Tullow, 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 approximately $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. For PetroSA, the pre-emption process is ongoing and remains subject to execution of definitive agreements and required government approvals. Following completion of the pre-emption for PetroSA, Kosmos' ultimate interests in the Jubilee Unit Area and TEN fields would be reduced to 38.3% and 19.8%, respectively. In March 2022, Kosmos completed the acquisition of an additional 5.5% interest in the Winterfell area in Green Canyon Blocks 943, 944, 987 and 988, offshore U.S. Gulf of Mexico, 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 now 37.8%. In May 2022, Kosmos and its joint venture partners agreed with the Ministry of Mines and Hydrocarbons 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. As part of the extension, during the second quarter of 2022, Kosmos paid a signature bonus and agreed to undertake a work program including the drilling of three development wells on Block G in either the Ceiba Field or Okume Complex and the drilling of one exploration well in Block S offshore Equatorial Guinea. 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, which increased our working interest from 29.1% to 35.0%. As consideration for the acquisition, Kosmos paid approximately $21.2 million in cash with additional deferred payments of $7.8 million 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. In June 2022, at the conclusion of the second exploration period, Block C12 offshore Mauritania was relinquished.

Joint Interest Billings and Lon

Joint Interest Billings and Long-term Receivables	9 Months Ended
	Sep. 30, 2022
Joint Interest Billings
Joint Interest Billings and Long-term Receivables	Joint Interest Billings and Long-term Receivables Joint Interest Billings 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 on the face of the consolidated balance sheets as current and long-term receivables based on when collection is expected to occur. In Ghana, the foreign contractor group funded GNPC’s 5% share of the TEN development costs. The foreign contractor group is being reimbursed for such costs plus interest out of a portion of GNPC’s TEN production revenues. As of September 30, 2022 and December 31, 2021, the current portions of the joint interest billing receivables due from GNPC for the TEN fields development costs were $7.9 million and $7.9 million, respectively, and the long-term portions were $21.1 million and $20.9 million, respectively. Notes 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 company’s share of certain development costs incurred through first gas production for Greater Tortue Ahmeyim Phase 1, currently targeted in the third quarter of 2023. Kosmos’ share for the two agreements combined is currently estimated at approximately $240.0 million, which is to be repaid with interest through the national oil companies’ share of future revenues. As of September 30, 2022 and December 31, 2021, the balance due from the national oil companies was $179.3 million and $145.2 million, respectively, which is classified as Long-term receivables on our consolidated balance sheets. Interest income on the long-term notes receivable was $2.5 million and $1.8 million for the three months ended September 30, 2022 and 2021, respectively, and $6.8 million and $5.4 million for the nine months ended September 30, 2022 and 2021, respectively. Other Long-term Receivables 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 (which is currently under construction by Technip Energies in China) to an affiliate of BP (“BP Buyer”). The Greater Tortue FPSO will be leased back to BP Operator under a long-term lease agreement, for exclusive use in the Greater Tortue project. BP Operator will continue to manage and supervise the construction contract with Technip Energies. Delivery of the Greater Tortue FPSO to BP Buyer will occur after construction is complete and the Greater Tortue FPSO has been commissioned, with the lease to BP Operator becoming effective on the same date, currently targeted to be in the third quarter of 2023. 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 September 30, 2022, this Long-term receivable has been 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. These non-cash impacts are excluded from the statement of cash flows.

Property and Equipment

Property and Equipment	9 Months Ended
	Sep. 30, 2022
Property, Plant and Equipment [Abstract]
Property and Equipment	Property and Equipment Property and equipment is stated at cost and consisted of the following: September 30, December 31, (In thousands) Oil and gas properties: Proved properties $ 7,050,725 $ 6,725,453 Unproved properties 434,574 451,454 Total oil and gas properties 7,485,299 7,176,907 Accumulated depletion (3,352,337) (2,999,584) Oil and gas properties, net 4,132,962 4,177,323 Other property 60,419 58,598 Accumulated depreciation (54,714) (51,934) Other property, net 5,705 6,664 Property and equipment, net $ 4,138,667 $ 4,183,987 We recorded depletion expense of $100.0 million and $58.8 million for the three months ended September 30, 2022 and 2021, respectively, and $366.4 million and $274.6 million for the nine months ended September 30, 2022 and 2021, respectively. During the nine months ended September 30, 2022 our oil and gas properties, net balance was reduced by approximately $175.5 million as a result of concluding the Tullow pre-emption transaction in March 2022, $64.2 million as a result of the write-off of previously capitalized costs related to the BirAllah and Orca discoveries incurred under the C8 license to exploration expense, offset by additions of $53.1 million related to the acquisition of an additional working interest in the Kodiak oil field, the extension of the Block G licenses in Equatorial Guinea, and the acquisitions of additional participating interests in the Winterfell area. See Note 3 — Acquisitions and Divestitures and Note 6 — Suspended Well Costs.

Suspended Well Costs

Suspended Well Costs	9 Months Ended
	Sep. 30, 2022
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Suspended Well Costs	Suspended Well Costs The following table reflects the Company’s capitalized exploratory well costs on drilled wells as of and during the nine months ended September 30, 2022. September 30, (In thousands) Beginning balance $ 218,180 Additions to capitalized exploratory well costs pending the determination of proved reserves 22,037 Reclassification due to determination of proved reserves — Capitalized exploratory well costs charged to expense (62,818) Ending balance $ 177,399 The following table provides an 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: September 30, December 31, (In thousands, except project counts) Exploratory well costs capitalized for a period of one year or less $ — $ 20,903 Exploratory well costs capitalized for a period of one to three years 65,890 30,389 Exploratory well costs capitalized for a period of four to six years 111,509 166,888 Ending balance $ 177,399 $ 218,180 Number of projects that have exploratory well costs that have been capitalized for a period greater than one year 3 3 As of September 30, 2022, 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, the Asam discovery in Block S offshore Equatorial Guinea, and the Winterfell discovery in Green Canyon Block 944 in the U.S. Gulf of Mexico. BirAllah and Orca Discoveries — In November 2015, we completed the Marsouin-1 exploration well in the northern part of Block C8 offshore Mauritania, which encountered hydrocarbon pay. During the fourth quarter of 2019, we completed the nearby Orca-1 exploration well which encountered hydrocarbon pay. The BirAllah and Orca discoveries are being analyzed as a joint development. In June 2022, the exploration period of Block C8 offshore Mauritania expired. As a result, during the second quarter of 2022 we wrote off all of the capitalized costs, or $64.2 million, related to the BirAllah and Orca discoveries incurred under the C8 license to exploration expense. In October 2022, the partnership and the government of Mauritania executed a new Production Sharing Contract (“PSC”) covering these discoveries, which will become effective upon being published in Mauritania’s Official Gazette. Yakaar and Teranga Discoveries — In May 2016, we completed the Teranga-1 exploration well in the Cayar Offshore Profond block offshore Senegal, which encountered hydrocarbon pay. In June 2017, we completed 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 completed 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 July 2021, the current phase of the Cayar Block exploration license was extended up to an additional three years to 2024. The Yakaar and Teranga discoveries are being analyzed as a joint development. During 2022, we have continued progressing appraisal studies and maturing concept design. Following additional evaluation, a decision regarding commerciality is expected to be made. Asam Discovery — In October 2019, we completed the S-5 exploration well offshore Equatorial Guinea, which encountered hydrocarbon pay. In July 2020, an appraisal plan was approved by the government of Equatorial Guinea. The well is located within tieback range of the Ceiba FPSO and work is currently ongoing to integrate all available data into models to establish the scale of the discovered resource. The active phase of the Block S exploration license is currently set to expire in December 2022. During 2022, engineering has continued to progress concepts around required subsea infrastructure necessary for a subsea tieback. Following additional evaluation, a decision regarding commerciality is expected to be made. Winterfell Discovery — In January 2021, we drilled the Winterfell-1 exploration well located in Green Canyon Block 944 in the U.S. Gulf of Mexico, which encountered hydrocarbon pay. In January 2022, we drilled the Winterfell-2 appraisal well which encountered hydrocarbon pay. During the third quarter of 2022, the Field Development Plan for the Winterfell field was approved by all partners. Execution of a host facility production handling agreement and midstream export agreement are in process.

Debt

Debt	9 Months Ended
	Sep. 30, 2022
Debt Disclosure [Abstract]
Debt	Debt September 30, December 31, (In thousands) Outstanding debt principal balances: Facility $ 700,000 $ 1,000,000 7.125% Senior Notes 650,000 650,000 7.750% Senior Notes 400,000 400,000 7.500% Senior Notes 450,000 450,000 GoM Term Loan 152,500 175,000 Total 2,352,500 2,675,000 Unamortized deferred financing costs and discounts (46,731) (54,505) Total debt, net 2,305,769 2,620,495 Less: Current maturities of long-term debt (30,000) (30,000) Long-term debt, net $ 2,275,769 $ 2,590,495 __________________________________ Facility The Facility supports our oil and gas exploration, appraisal and development programs and corporate activities. As of September 30, 2022, borrowings under the Facility totaled $700.0 million and the undrawn availability under the facility was $550.0 million. During the nine months ended September 30, 2022, the Company made principal repayments totaling $300.0 million on the Facility including $100.0 million with the proceeds from the Tullow pre-emption transaction. See Note 3 — Acquisitions and Divestitures. Final maturity of the Facility is in March 2027. As part of the last amendment to the Facility in May 2021, the Company incurred $15.2 million for loss on extinguishment of debt during the second quarter of 2021. In October 2022, during the Fall 2022 redetermination, the Company’s lending syndicate approved a borrowing base of approximately $1.24 billion. 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 Company’s production assets in Ghana (excluding the additional interests in Jubilee and TEN acquired in the acquisition of Anadarko WCTP in October 2021) and Equatorial Guinea. 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 and the 7.500% Senior Notes plus the Corporate Revolver or the Facility, whichever is greater. As of March 31, 2022 our net leverage ratio was below 2.50x, and therefore, we released $59.1 million from restricted cash in May 2022 upon submission of the net leverage test as of March 31, 2022. As of September 30, 2022 our net leverage ratio remained below 2.50x. We were in compliance with the financial covenants contained in the Facility as of September 30, 2022 (the most recent assessment date). The Facility, as amended, 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 resulting in the following changes to the terms : • The total size of the Corporate Revolver is reduced from $400 million to $250 million. • The maturity date is extended from May 2022 to December 31, 2024. • Borrowings under the Corporate Revolver now bear interest at a rate equal to the secured overnight financing rate administered by the Federal Reserve Bank of New York plus a credit adjustment spread plus a 7.0% margin plus mandatory costs, if applicable. • Addition of a negative pledge covenant over the participating interests held by the Company’s wholly-owned subsidiary, Kosmos Energy Ghana Investments, in the WCTP and DT blocks offshore Ghana. • As the Corporate Revolver is intended to continue to largely remain undrawn, the Company is required to use the proceeds from any capital markets and loan transactions to first repay any drawn outstanding balance under the Corporate Revolver and the Company is subject to a cash sweep of at least 50% of the Company’s Excess Cash (as defined in the Corporate Revolver) to pay outstanding balances as of March 31 or September 30 in any calendar year. The Company capitalized $6.1 million of deferred financing costs associated with entering into the new revolving credit facility, which will be amortized over the term of the new revolving credit facility. As of September 30, 2022, there were no outstanding borrowings under the Corporate Revolver and the undrawn availability was $250.0 million The Corporate Revolver is available for general corporate purposes and for oil and gas exploration, appraisal and development programs. We were in compliance with the financial covenants contained in the Corporate Revolver as of September 30, 2022 (the most recent assessment date). The Corporate Revolver contains customary cross default provisions. 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 in 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. Interest is payable in arrears 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 Corporate Revolver, 7.750% Senior Notes and the 7.500% 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) and all borrowings under the GoM Term Loan. The 7.125% Senior Notes are guaranteed on a senior, unsecured basis by certain subsidiaries owning the Company's U.S. Gulf of Mexico assets and the interests acquired in the Anadarko WCTP acquisition, and on a subordinated, unsecured basis by certain subsidiaries that borrow under, or guarantee, the Facility and that guarantee the Corporate Revolver, the 7.750% Senior Notes and the 7.500% Senior Notes. 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 in 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 Corporate Revolver, the 7.125% Senior Notes and the 7.500% 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) and all borrowings under the GoM Term Loan. The 7.750% Senior Notes are guaranteed on a senior, unsecured basis by certain subsidiaries owning the Company's U.S. Gulf of Mexico assets and the interests acquired in the Anadarko WCTP acquisition, and on a subordinated, unsecured basis by certain subsidiaries that borrow under, or guarantee, the Facility and that guarantee the Corporate Revolver, the 7.125% Senior Notes and the 7.500% Senior Notes. 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 Corporate Revolver, the 7.125% Senior Notes and the 7.750% 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) and all borrowings under the GoM Term Loan. The 7.500% Senior Notes are guaranteed on a senior, unsecured basis by certain subsidiaries owning the Company's U.S. Gulf of Mexico assets and the interests in the Anadarko WCTP acquisition, and on a subordinated, unsecured basis by certain subsidiaries that borrow under, or guarantee, the Facility and that guarantee the Corporate Revolver, and the 7.125% Senior Notes and the 7.750% Senior Notes. The 7.500% Senior Notes contain customary cross default provisions. GoM Term Loan In September 2020, the Company entered into a five-year $200.0 million senior secured term-loan credit agreement secured against the Company's U.S. Gulf of Mexico assets with net proceeds received of $197.7 million after deducting fees and other expenses. The GoM Term Loan also includes an accordion feature providing for incremental commitments of up to $100.0 million subject to certain conditions. The GoM Term Loan bears interest at an effective rate of approximately 6.6% per annum and matures in 2025, with quarterly principal repayments having started since the fourth quarter of 2021. As of September 30, 2022, $30.0 million of the total $152.5 million outstanding under the GoM Term Loan have been classified within Current maturities of long-term debt on our consolidated balance sheet. We were in compliance with the covenants, representations and warranties contained in the GoM Term Loan as of September 30, 2022 (the most recent assessment date). The GoM Term Loan contains customary cross default provisions as well as maturity acceleration provisions if certain Permitted Guaranteed Facilities are not refinanced prior to scheduled maturity. Principal Debt Repayments At September 30, 2022, the estimated repayments of debt during the five fiscal year periods and thereafter are as follows: Payments Due by Year Total 2022(2) 2023 2024 2025 2026 Thereafter (In thousands) Principal debt repayments(1) $ 2,352,500 $ 7,500 $ 30,000 $ 30,000 $ 254,011 $ 1,002,418 $ 1,028,571 __________________________________ (1) Includes the scheduled maturities for outstanding principal debt balances. The scheduled maturities of debt related to the Facility as of September 30, 2022 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. (2) Represents payments for the period October 1, 2022 through December 31, 2022. Interest and other financing costs, net Interest and other financing costs, net incurred during the periods is comprised of the following: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (In thousands) Interest expense $ 45,448 $ 36,055 $ 131,626 $ 103,229 Amortization—deferred financing costs 2,577 2,597 7,838 7,788 Loss on extinguishment of debt — — 192 15,223 Capitalized interest (22,163) (12,252) (57,489) (31,956) Deferred interest 4 (600) (1,436) (724) Interest income (2,956) (2,237) (7,840) (8,309) Other, net 6,886 3,310 19,426 5,476 Interest and other financing costs, net $ 29,796 $ 26,873 $ 92,317 $ 90,727

Derivative Financial Instrument

Derivative Financial Instruments	9 Months Ended
	Sep. 30, 2022
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 Measurement. 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 September 30, 2022. Volumes and weighted average prices are net of any offsetting derivative contracts entered into. Weighted Average Price per Bbl Net Deferred Premium Payable/ Sold Term Type of Contract Index MBbl (Receivable) Put Floor Ceiling 2022: Oct — Dec Three-way collars Dated Brent 1,125 $ 0.64 $ 43.33 $ 56.67 $ 76.91 Oct — Dec Three-way collars NYMEX WTI 250 1.45 50.00 65.00 85.00 Oct — Dec Two-way collars Dated Brent 1,500 1.22 — 62.50 83.33 Oct — Dec Sold calls(1) Dated Brent 395 — — — 60.00 2023: Jan — Dec Three-way collars Dated Brent 4,000 1.21 48.75 70.00 106.38 Jan — Dec Two-way collars Dated Brent 2,000 2.50 — 75.00 125.00 __________________________________ (1) Represents call option contracts sold to counterparties to enhance other derivative positions In October 2022, we entered into Dated Brent three-way collar contracts for 1.0 MMBbl from January 2023 through December 2023 with a sold put price of $50.00 per barrel, a floor price of $75.00 per barrel and a ceiling price of $110.00 per barrel. In addition, we entered into Dated Brent two-way collar contracts for 2.0 MMBbl from January 2023 through December 2023 with a floor price of $70.00 per barrel and a ceiling price of $110.00 per barrel. The following tables disclose the Company’s derivative instruments as of September 30, 2022 and December 31, 2021, and gain/(loss) from derivatives during the three and nine months ended September 30, 2022 and 2021, respectively: Estimated Fair Value Asset (Liability) Type of Contract Balance Sheet Location September 30, December 31, (In thousands) Derivatives not designated as hedging instruments: Derivative assets: Commodity Derivatives assets—current $ 11,879 $ 5,689 Provisional oil sales Receivables: Oil Sales — (853) Commodity Derivatives assets—long-term 8,646 1,026 Derivative liabilities: Commodity Derivatives liabilities—current (37,477) (65,879) Commodity Derivatives liabilities—long-term (2,147) (6,298) Total derivatives not designated as hedging instruments $ (19,099) $ (66,315) Amount of Gain/(Loss) Amount of Gain/(Loss) Three Months Ended Nine Months Ended September 30, September 30, Type of Contract Location of Gain/(Loss) 2022 2021 2022 2021 (In thousands) Derivatives not designated as hedging instruments: Provisional oil sales Oil and gas revenue $ (3,580) $ 2,094 $ (13,578) $ (6,683) Commodity Derivatives, net 113,842 (38,224) (243,534) (252,606) Total derivatives not designated as hedging instruments $ 110,262 $ (36,130) $ (257,112) $ (259,289) 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 September 30, 2022 and December 31, 2021, 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	9 Months Ended
	Sep. 30, 2022
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements In accordance with ASC 820 — Fair Value Measurement, 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 September 30, 2022 and December 31, 2021, for each fair value hierarchy level: Fair Value Measurements Using: Quoted Prices in Active Markets for Significant Other Significant Identical Assets Observable Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Total (In thousands) September 30, 2022 Assets: Commodity derivatives $ — $ 20,525 $ — $ 20,525 Provisional oil sales — — — — Liabilities: Commodity derivatives — (39,624) — (39,624) Total $ — $ (19,099) $ — $ (19,099) December 31, 2021 Assets: Commodity derivatives $ — $ 6,715 $ — $ 6,715 Provisional oil sales — (853) — (853) Liabilities: Commodity derivatives — (72,177) — (72,177) Total $ — $ (66,315) $ — $ (66,315) 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 and call options for notional barrels of oil at fixed Dated Brent or NYMEX WTI 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 8 — Derivative Financial Instruments for additional information regarding the Company’s derivative instruments. Provisional Oil Sales The value attributable to provisional oil sales derivatives 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. Debt The following table presents the carrying values and fair values at September 30, 2022 and December 31, 2021: September 30, 2022 December 31, 2021 Carrying Value Fair Value Carrying Value Fair Value (In thousands) 7.125% Senior Notes $ 645,409 $ 534,034 $ 644,572 $ 632,587 7.750% Senior Notes 395,697 320,992 395,131 386,428 7.500% Senior Notes 445,391 352,598 444,892 424,688 GoM Term Loan 152,500 152,500 175,000 175,000 Facility 700,000 700,000 1,000,000 1,000,000 Total $ 2,338,997 $ 2,060,124 $ 2,659,595 $ 2,618,703 The carrying values of our 7.125% Senior Notes, 7.750% Senior Notes and 7.500% Senior Notes represent the principal amounts outstanding less unamortized discounts. The fair values of our 7.125% Senior Notes, 7.750% Senior Notes and 7.500% Senior Notes are based on quoted market prices, which results in a Level 1 fair value measurement. The carrying values of the GoM Term Loan and 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. During the three and nine months ended September 30, 2022 and 2021, the Company did not recognize impairment of proved oil and gas properties as no impairment indicators were identified. If we experience significant declines in oil pricing expectations in the future, significant increases in our estimated future expenditures or a significant decrease in our estimated production profile, our long-lived assets could be at risk of additional impairment.

Equity-based Compensation

Equity-based Compensation	9 Months Ended
	Sep. 30, 2022
Share-Based Payment Arrangement [Abstract]
Equity-based Compensation	Equity-based Compensation Restricted Stock Units We record equity-based compensation expense equal to the fair value of share-based payments over the vesting periods of the LTIP awards. We recorded compensation expense from awards granted under our LTIP of $8.8 million and $8.1 million during the three months ended September 30, 2022 and 2021, respectively, and $25.9 million and $24.0 million during the nine months ended September 30, 2022 and 2021, respectively. The total tax benefit for the three months ended September 30, 2022 and 2021 was $1.5 million and $1.5 million, respectively, and $4.4 million and $4.5 million during the nine months ended September 30, 2022 and 2021, respectively. Additionally, we recorded a net tax shortfall related to equity-based compensation of nil and $1.5 million for the three months ended September 30, 2022 and 2021, respectively, and $0.7 million and $6.3 million during the nine months ended September 30, 2022 and 2021, respectively. The fair value of awards vested during the three months ended September 30, 2022 and 2021 was $0.5 million and $1.0 million, respectively, and $21.9 million and $9.4 million during the nine months ended September 30, 2022 and 2021, respectively. The Company granted restricted stock units with service vesting criteria and a combination of market and service vesting criteria under the LTIP. Substantially all of these grants vest over three years. Upon vesting, restricted stock units become issued and outstanding stock. The following table reflects the outstanding restricted stock units as of September 30, 2022: Weighted- Market / Service Weighted- Service Vesting Average Vesting Average Restricted Stock Grant-Date Restricted Stock Grant-Date Units Fair Value Units Fair Value (In thousands) (In thousands) Outstanding at December 31, 2021 4,696 $ 3.88 11,233 $ 5.28 Granted(1) 2,793 4.70 3,378 6.97 Forfeited(1) (145) 3.91 (389) 6.19 Vested (2,413) 4.20 (2,175) 5.98 Outstanding at September 30, 2022 4,931 4.18 12,047 5.61 __________________________________ (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 September 30, 2022, total equity-based compensation to be recognized on unvested restricted stock units is $28.5 million over a weighted average period of 1.78 years. At September 30, 2022, the Company had approximately 6.0 million shares that remain available for issuance under the LTIP. 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 $12.33 per award. The Monte Carlo simulation model utilized multiple input variables that determined the probability of satisfying the market condition stipulated in the award grant and calculated 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 104.8%. The risk-free interest rate was based on the U.S. treasury rate for a term commensurate with the expected life of the grant and ranged from 0.2% to 2.5%.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes We evaluate our estimated annual effective income tax rate each quarter, based on current and forecasted business results and enacted tax laws, and apply this tax rate to our ordinary income or loss to calculate our estimated tax expense or benefit. The Company excludes zero tax rate and tax-exempt jurisdictions from our evaluation of the estimated annual effective income tax rate. The tax effect of discrete items are recognized in the period in which they occur at the applicable statutory tax rate. During the nine months ended September 30, 2022, our deferred tax liability decreased by approximately $81.3 million. Approximately $44.6 million of the decrease is the result of concluding the Tullow pre-emption transaction in March 2022. See Note 3 - Acquisitions and Divestitures. The remaining $36.7 million decrease in our deferred tax liability is primarily the result of originating and reversing temporary differences. Income (loss) before income taxes is composed of the following: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (In thousands) United States $ 16,168 $ (19,129) $ 77,832 $ (57,769) Foreign 313,799 (8,847) 459,139 (141,400) Income (loss) before income taxes $ 329,967 $ (27,976) $ 536,971 $ (199,169) For the three months ended, September 30, 2022 and 2021, our effective tax rate was 33% and 2%, respectively. For the nine months ended, September 30, 2022 and 2021, our effective tax rate was 37% and 11%, respectively. For the three and nine months ended September 30, 2022 and 2021, our overall effective tax rates were impacted by: • The difference in our 21% U.S. income tax reporting rate and the 35% statutory tax rates applicable to our Ghanaian and Equatorial Guinean operations, • Jurisdictions that have a 0% statutory rate or where we have incurred losses and have recorded valuation allowances against the corresponding deferred tax assets, and • Other non-deductible expenses primarily in the U.S.

Net Income (Loss) Per Share

Net Income (Loss) Per Share	9 Months Ended
	Sep. 30, 2022
Earnings Per Share [Abstract]
Net Income (Loss) Per Share	Net Income (Loss) Per Share The following table is a reconciliation between net income (loss) and the amounts used to compute basic and diluted net income (loss) per share and the weighted average shares outstanding used to compute basic and diluted net income (loss) per share: Three Months Ended Nine Months Ended September 30, September 30, 2022 2021 2022 2021 (In thousands, except per share data) Numerator: Net income (loss) allocable to common stockholders $ 222,254 $ (28,597) $ 340,827 $ (176,552) Denominator: Weighted average number of shares outstanding: Basic 455,840 408,520 455,158 408,009 Restricted stock units(1) 20,591 — 19,662 — Diluted 476,431 408,520 474,820 408,009 Net income (loss) per share: Basic $ 0.49 $ (0.07) $ 0.75 $ (0.43) Diluted $ 0.47 $ (0.07) $ 0.72 $ (0.43) __________________________________ (1) We excluded restricted stock units of 0.2 million and 15.4 million for the three months ended September 30, 2022 and 2021, respectively, and 0.1 million and 15.0 million for the nine months ended September 30, 2022 and 2021, respectively, from the computations of diluted net income (loss) per share because the effect would have been anti-dilutive.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2022
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. We have a commitment to drill three development wells and one exploration well in Equatorial Guinea. In Mauritania, we have a $200.2 million FPSO Contract Liability related to the deferred sale of the Greater Tortue FPSO. Performance Obligations

Additional Financial Informatio

Additional Financial Information	9 Months Ended
	Sep. 30, 2022
Additional Financial Information
Additional Financial Information	Additional Financial Information Accrued Liabilities Accrued liabilities consisted of the following: September 30, December 31, (In thousands) Accrued liabilities: Exploration, development and production $ 54,901 $ 61,881 Revenue payable 21,830 31,986 Current asset retirement obligations 3,234 3,222 General and administrative expenses 23,886 27,980 Interest 28,800 31,117 Income taxes 105,963 69,392 Taxes other than income 1,547 2,854 Derivatives 6,311 19,302 Other 5,724 2,936 $ 252,196 $ 250,670 Asset Retirement Obligations The following table summarizes the changes in the Company's asset retirement obligations as of and during the nine months ended September 30, 2022: September 30, (In thousands) Asset retirement obligations: Beginning asset retirement obligations $ 325,459 Liabilities incurred during period 11,964 Liabilities settled during period (10,532) Revisions in estimated retirement obligations (65,552) Accretion expense 17,762 Ending asset retirement obligations $ 279,101 During the nine months ended September 30, 2022 our asset retirement obligations were reduced by approximately $10.0 million as a result of concluding the Tullow pre-emption transaction in March 2022 and approximately $66.2 million as a result of the extension of the Block G licenses in Equatorial Guinea in May 2022. See Note 3 — Acquisitions and Divestitures. Other Expenses, Net Other expenses, net incurred during the period is comprised of the following: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (In thousands) (Gain) loss on disposal of inventory $ (821) $ (280) $ (536) $ 302 Loss on asset retirement obligations liability settlements — 58 620 444 Restructuring charges — (127) (4) 710 Other, net 603 543 (1,400) (453) Other expenses, net $ (218) $ 194 $ (1,320) $ 1,003

Business Segment Information

Business Segment Information	9 Months Ended
	Sep. 30, 2022
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 September 30, 2022, the Company had operations in four geographic reporting segments: Ghana, Equatorial Guinea, Mauritania/Senegal and the U.S. Gulf of Mexico. To assess performance of the reporting segments, the Chief Operating Decision Maker reviews capital expenditures. 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 area is presented below: Ghana(2) Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico(3) Corporate & Other Eliminations Total (In thousands) Three months ended September 30, 2022 Revenues and other income: Oil and gas revenue $ 296,980 $ 42,473 $ — $ 116,603 $ — $ — $ 456,056 Other income, net 1 — — 698 (82,537) 81,886 48 Total revenues and other income 296,981 42,473 — 117,301 (82,537) 81,886 456,104 Costs and expenses: Oil and gas production 23,911 11,921 — 26,540 — — 62,372 Facilities insurance modifications, net 494 — — — — — 494 Exploration expenses 9,459 1,071 2,182 2,674 1,829 — 17,215 General and administrative 3,967 1,991 2,624 2,804 44,577 (31,956) 24,007 Depletion, depreciation and amortization 65,288 7,741 143 32,701 440 — 106,313 Interest and other financing costs, net(1) 16,922 (595) (18,402) 2,785 29,086 — 29,796 Derivatives, net — — — — (113,842) — (113,842) Other expenses, net (101,457) (6,464) 145 (6,317) 33 113,842 (218) Total costs and expenses 18,584 15,665 (13,308) 61,187 (37,877) 81,886 126,137 Income (loss) before income taxes 278,397 26,808 13,308 56,114 (44,660) — 329,967 Income tax expense (benefit) 98,413 7,371 — (275) 2,204 — 107,713 Net income (loss) $ 179,984 $ 19,437 $ 13,308 $ 56,389 $ (46,864) $ — $ 222,254 Consolidated capital expenditures, net $ 40,871 $ 2,435 $ 114,339 $ 43,612 $ 1,834 $ — $ 203,091 Ghana(2) Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico(3) Corporate & Other Eliminations Total (In thousands) Nine months ended September 30, 2022 Revenues and other income: Oil and gas revenue $ 1,032,551 $ 261,442 $ — $ 441,446 $ — $ — $ 1,735,439 Gain on sale of assets — — — 471 — — 471 Other income, net 1 — — 1,726 340,768 (342,352) 143 Total revenues and other income 1,032,552 261,442 — 443,643 340,768 (342,352) 1,736,053 Costs and expenses: Oil and gas production 137,030 60,384 — 79,850 — — 277,264 Facilities insurance modifications, net 7,246 — — — — — 7,246 Exploration expenses 11,433 4,047 80,271 19,770 3,135 — 118,656 General and administrative 11,379 5,008 6,890 11,181 138,783 (98,817) 74,424 Depletion, depreciation and amortization 229,074 40,729 257 115,648 1,253 — 386,961 Interest and other financing costs, net(1) 46,208 (1,682) (46,903) 8,244 86,450 — 92,317 Derivatives, net — — — — 243,534 — 243,534 Other expenses, net 215,340 17,553 (1,200) 11,355 (834) (243,534) (1,320) Total costs and expenses 657,710 126,039 39,315 246,048 472,321 (342,351) 1,199,082 Income (loss) before income taxes 374,842 135,403 (39,315) 197,595 (131,553) (1) 536,971 Income tax expense (benefit) 133,193 55,420 — 2,828 4,703 — 196,144 Net income (loss) $ 241,649 $ 79,983 $ (39,315) $ 194,767 $ (136,256) $ (1) $ 340,827 Consolidated capital expenditures, net $ 32,814 $ 26,732 $ 261,755 $ 107,856 $ 4,545 $ — $ 433,702 As of September 30, 2022 Property and equipment, net $ 1,627,871 $ 385,442 $ 1,225,991 $ 881,990 $ 17,373 $ — $ 4,138,667 Total assets $ 3,211,263 $ 1,130,390 $ 1,727,997 $ 3,649,195 $ 18,987,516 $ (23,784,949) $ 4,921,412 ______________________________________ (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 reduction in Consolidated capital expenditures for the nine months ended September 30, 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 Consolidated capital expenditures for the nine months ended September 30, 2022. Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Three months ended September 30, 2021 Revenues and other income: Oil and gas revenue $ 67,247 $ 35,063 $ — $ 96,626 $ — $ — $ 198,936 Gain on sale of assets — — — — 1,538 — 1,538 Other income, net — — — 256 65,941 (66,131) 66 Total revenues and other income 67,247 35,063 — 96,882 67,479 (66,131) 200,540 Costs and expenses: Oil and gas production 10,490 13,029 — 26,797 — — 50,316 Facilities insurance modifications, net 1,555 — — — (1) — 1,554 Exploration expenses 89 2,089 7,081 13,975 748 — 23,982 General and administrative 3,165 581 2,980 4,177 39,464 (27,908) 22,459 Depletion, depreciation and amortization 20,958 5,999 15 37,551 391 — 64,914 Interest and other financing costs, net(1) 16,836 (446) (11,604) 3,446 18,641 — 26,873 Derivatives, net — — — — 38,224 — 38,224 Other expenses, net 34,382 3,229 (106) 648 265 (38,224) 194 Total costs and expenses 87,475 24,481 (1,634) 86,594 97,732 (66,132) 228,516 Income (loss) before income taxes (20,228) 10,582 1,634 10,288 (30,253) 1 (27,976) Income tax expense (benefit) (6,782) 5,758 — — 1,645 — 621 Net income (loss) $ (13,446) $ 4,824 $ 1,634 $ 10,288 $ (31,898) $ 1 $ (28,597) Consolidated capital expenditures, net $ 30,935 $ 20,351 $ 13,734 $ 21,188 $ (162) $ — $ 86,046 Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Nine months ended September 30, 2021 Revenues and other income: Oil and gas revenue $ 313,126 $ 147,424 $ — $ 298,905 $ — $ — $ 759,455 Gain on sale of assets — — — — 1,564 — 1,564 Other income, net 1 — — 1,028 347,866 (348,685) 210 Total revenues and other income 313,127 147,424 — 299,933 349,430 (348,685) 761,229 Costs and expenses: Oil and gas production 80,189 56,373 — 75,309 — — 211,871 Facilities insurance modifications, net 3,495 — — — — — 3,495 Exploration expenses 164 4,666 10,812 20,541 5,269 — 41,452 General and administrative 8,636 2,883 7,677 12,620 129,108 (94,296) 66,628 Depletion, depreciation and amortization 132,232 34,474 46 124,598 1,266 — 292,616 Interest and other financing costs, net(1) 36,890 (1,218) (33,816) 12,307 78,348 (1,784) 90,727 Derivatives, net — — — — 252,606 — 252,606 Other expenses, net 193,370 34,096 (2,348) 26,185 2,306 (252,606) 1,003 Total costs and expenses 454,976 131,274 (17,629) 271,560 468,903 (348,686) 960,398 Income (loss) before income taxes (141,849) 16,150 17,629 28,373 (119,473) 1 (199,169) Income tax expense (benefit) (48,770) 19,957 — — 6,196 — (22,617) Net income (loss) $ (93,079) $ (3,807) $ 17,629 $ 28,373 $ (125,669) $ 1 $ (176,552) Consolidated capital expenditures, net $ 61,570 $ 51,444 $ 169,158 $ 65,674 $ 5,564 $ — $ 353,410 As of September 30, 2021 Property and equipment, net $ 1,226,513 $ 447,795 $ 822,013 $ 925,384 $ 21,192 $ — $ 3,442,897 Total assets $ 1,297,303 $ 854,530 $ 1,329,267 $ 3,216,368 $ 14,315,531 $ (16,859,275) $ 4,153,724 ______________________________________ (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. Nine Months Ended September 30, 2022 2021 (In thousands) Consolidated capital expenditures: Consolidated Statements of Cash Flows - Investing activities: Oil and gas assets $ 543,349 $ 377,850 Acquisition of oil and gas properties 21,205 — Proceeds on sale of assets (118,703) (5,327) Adjustments: Changes in capital accruals 1,511 (16,523) Exploration expense, excluding unsuccessful well costs and leasehold impairments(1) 35,570 24,680 Capitalized interest (57,489) (31,956) Other 8,259 4,686 Total consolidated capital expenditures, net $ 433,702 $ 353,410 ______________________________________ (1) Unsuccessful well costs and leasehold impairments are included in oil and gas assets when incurred.

Accounting Policies (Policies)

Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2022
Accounting Policies [Abstract]
General	General The interim consolidated financial statements included in this report are unaudited and, in the opinion of management, include all adjustments of a normal recurring nature necessary for a fair presentation of the results for the interim periods. The results of the interim periods shown in this report are not necessarily indicative of the final results to be expected for the full year. The interim consolidated financial statements were prepared in accordance with the requirements of the SEC for interim reporting. As permitted under those rules, certain notes or other financial information that are normally required by GAAP have been condensed or omitted from these interim consolidated financial statements. These interim consolidated financial statements and the accompanying notes should be read in conjunction with our audited consolidated financial statements for the year ended December 31, 2021, included in our annual report on Form 10-K.
Reclassifications	Reclassifications
Cash, Cash Equivalents and Restricted Cash	Cash, Cash Equivalents and Restricted CashCash and cash equivalents include 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 and the 7.500% Senior Notes plus the Corporate Revolver or the Facility, whichever is greater.
Inventories	InventoriesThe 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.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.
Revenue Recognition	Revenue Recognition 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 provisional price contracts which contain an embedded derivative that is required to be 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 embedded 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 after the sale.
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 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 operations. The continued economic disruption and volatility in the global and industry-wide markets resulting from the COVID-19 pandemic, Russia’s invasion of Ukraine, a potential global recession, 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.

Accounting Policies (Tables)

Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2022
Accounting Policies [Abstract]
Schedule of cash and cash equivalents	September 30, December 31, (In thousands) Cash and cash equivalents $ 231,565 $ 131,620 Restricted cash - current 27 42,971 Restricted cash - long-term 305 305 Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 231,897 $ 174,896
Schedule of oil and gas revenue	Oil and gas revenue is composed of the following: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (In thousands) Revenues from contract with customer - Equatorial Guinea $ 41,178 $ 34,247 $ 263,532 $ 145,378 Revenues from contract with customer - Ghana 301,855 65,969 1,044,039 321,855 Revenues from contract with customers - U.S. Gulf of Mexico 116,603 96,626 441,446 298,905 Provisional oil sales contracts (3,580) 2,094 (13,578) (6,683) Oil and gas revenue $ 456,056 $ 198,936 $ 1,735,439 $ 759,455

Property and Equipment (Tables)

Property and Equipment (Tables)	9 Months Ended
	Sep. 30, 2022
Property, Plant and Equipment [Abstract]
Schedule of property and equipment	Property and equipment is stated at cost and consisted of the following: September 30, December 31, (In thousands) Oil and gas properties: Proved properties $ 7,050,725 $ 6,725,453 Unproved properties 434,574 451,454 Total oil and gas properties 7,485,299 7,176,907 Accumulated depletion (3,352,337) (2,999,584) Oil and gas properties, net 4,132,962 4,177,323 Other property 60,419 58,598 Accumulated depreciation (54,714) (51,934) Other property, net 5,705 6,664 Property and equipment, net $ 4,138,667 $ 4,183,987

Suspended Well Costs (Tables)

Suspended Well Costs (Tables)	9 Months Ended
	Sep. 30, 2022
Oil and Gas Exploration and Production Industries Disclosures [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 nine months ended September 30, 2022. September 30, (In thousands) Beginning balance $ 218,180 Additions to capitalized exploratory well costs pending the determination of proved reserves 22,037 Reclassification due to determination of proved reserves — Capitalized exploratory well costs charged to expense (62,818) Ending balance $ 177,399
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 an 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: September 30, December 31, (In thousands, except project counts) Exploratory well costs capitalized for a period of one year or less $ — $ 20,903 Exploratory well costs capitalized for a period of one to three years 65,890 30,389 Exploratory well costs capitalized for a period of four to six years 111,509 166,888 Ending balance $ 177,399 $ 218,180 Number of projects that have exploratory well costs that have been capitalized for a period greater than one year 3 3

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2022
Debt Disclosure [Abstract]
Schedule of debt	September 30, December 31, (In thousands) Outstanding debt principal balances: Facility $ 700,000 $ 1,000,000 7.125% Senior Notes 650,000 650,000 7.750% Senior Notes 400,000 400,000 7.500% Senior Notes 450,000 450,000 GoM Term Loan 152,500 175,000 Total 2,352,500 2,675,000 Unamortized deferred financing costs and discounts (46,731) (54,505) Total debt, net 2,305,769 2,620,495 Less: Current maturities of long-term debt (30,000) (30,000) Long-term debt, net $ 2,275,769 $ 2,590,495
Schedule of estimated repayments of debt	At September 30, 2022, the estimated repayments of debt during the five fiscal year periods and thereafter are as follows: Payments Due by Year Total 2022(2) 2023 2024 2025 2026 Thereafter (In thousands) Principal debt repayments(1) $ 2,352,500 $ 7,500 $ 30,000 $ 30,000 $ 254,011 $ 1,002,418 $ 1,028,571 __________________________________ (1) Includes the scheduled maturities for outstanding principal debt balances. The scheduled maturities of debt related to the Facility as of September 30, 2022 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. (2) Represents payments for the period October 1, 2022 through December 31, 2022.
Schedule of interest and other financing costs, net	Interest and other financing costs, net incurred during the periods is comprised of the following: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (In thousands) Interest expense $ 45,448 $ 36,055 $ 131,626 $ 103,229 Amortization—deferred financing costs 2,577 2,597 7,838 7,788 Loss on extinguishment of debt — — 192 15,223 Capitalized interest (22,163) (12,252) (57,489) (31,956) Deferred interest 4 (600) (1,436) (724) Interest income (2,956) (2,237) (7,840) (8,309) Other, net 6,886 3,310 19,426 5,476 Interest and other financing costs, net $ 29,796 $ 26,873 $ 92,317 $ 90,727

Derivative Financial Instrume_2

Derivative Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of 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 September 30, 2022. Volumes and weighted average prices are net of any offsetting derivative contracts entered into. Weighted Average Price per Bbl Net Deferred Premium Payable/ Sold Term Type of Contract Index MBbl (Receivable) Put Floor Ceiling 2022: Oct — Dec Three-way collars Dated Brent 1,125 $ 0.64 $ 43.33 $ 56.67 $ 76.91 Oct — Dec Three-way collars NYMEX WTI 250 1.45 50.00 65.00 85.00 Oct — Dec Two-way collars Dated Brent 1,500 1.22 — 62.50 83.33 Oct — Dec Sold calls(1) Dated Brent 395 — — — 60.00 2023: Jan — Dec Three-way collars Dated Brent 4,000 1.21 48.75 70.00 106.38 Jan — Dec Two-way collars Dated Brent 2,000 2.50 — 75.00 125.00 __________________________________
Schedule of derivative instruments by balance sheet location	The following tables disclose the Company’s derivative instruments as of September 30, 2022 and December 31, 2021, and gain/(loss) from derivatives during the three and nine months ended September 30, 2022 and 2021, respectively: Estimated Fair Value Asset (Liability) Type of Contract Balance Sheet Location September 30, December 31, (In thousands) Derivatives not designated as hedging instruments: Derivative assets: Commodity Derivatives assets—current $ 11,879 $ 5,689 Provisional oil sales Receivables: Oil Sales — (853) Commodity Derivatives assets—long-term 8,646 1,026 Derivative liabilities: Commodity Derivatives liabilities—current (37,477) (65,879) Commodity Derivatives liabilities—long-term (2,147) (6,298) Total derivatives not designated as hedging instruments $ (19,099) $ (66,315)
Schedule of derivative instruments by location of gain/(loss)	Amount of Gain/(Loss) Amount of Gain/(Loss) Three Months Ended Nine Months Ended September 30, September 30, Type of Contract Location of Gain/(Loss) 2022 2021 2022 2021 (In thousands) Derivatives not designated as hedging instruments: Provisional oil sales Oil and gas revenue $ (3,580) $ 2,094 $ (13,578) $ (6,683) Commodity Derivatives, net 113,842 (38,224) (243,534) (252,606) Total derivatives not designated as hedging instruments $ 110,262 $ (36,130) $ (257,112) $ (259,289)

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2022
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 September 30, 2022 and December 31, 2021, for each fair value hierarchy level: Fair Value Measurements Using: Quoted Prices in Active Markets for Significant Other Significant Identical Assets Observable Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Total (In thousands) September 30, 2022 Assets: Commodity derivatives $ — $ 20,525 $ — $ 20,525 Provisional oil sales — — — — Liabilities: Commodity derivatives — (39,624) — (39,624) Total $ — $ (19,099) $ — $ (19,099) December 31, 2021 Assets: Commodity derivatives $ — $ 6,715 $ — $ 6,715 Provisional oil sales — (853) — (853) Liabilities: Commodity derivatives — (72,177) — (72,177) Total $ — $ (66,315) $ — $ (66,315)
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 September 30, 2022 and December 31, 2021: September 30, 2022 December 31, 2021 Carrying Value Fair Value Carrying Value Fair Value (In thousands) 7.125% Senior Notes $ 645,409 $ 534,034 $ 644,572 $ 632,587 7.750% Senior Notes 395,697 320,992 395,131 386,428 7.500% Senior Notes 445,391 352,598 444,892 424,688 GoM Term Loan 152,500 152,500 175,000 175,000 Facility 700,000 700,000 1,000,000 1,000,000 Total $ 2,338,997 $ 2,060,124 $ 2,659,595 $ 2,618,703

Equity-based Compensation (Tabl

Equity-based Compensation (Tables)	9 Months Ended
	Sep. 30, 2022
Share-Based Payment Arrangement [Abstract]
Schedule of outstanding restricted stock units	The following table reflects the outstanding restricted stock units as of September 30, 2022: Weighted- Market / Service Weighted- Service Vesting Average Vesting Average Restricted Stock Grant-Date Restricted Stock Grant-Date Units Fair Value Units Fair Value (In thousands) (In thousands) Outstanding at December 31, 2021 4,696 $ 3.88 11,233 $ 5.28 Granted(1) 2,793 4.70 3,378 6.97 Forfeited(1) (145) 3.91 (389) 6.19 Vested (2,413) 4.20 (2,175) 5.98 Outstanding at September 30, 2022 4,931 4.18 12,047 5.61 __________________________________ (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 .

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Schedule of components of income (loss) before income taxes	Income (loss) before income taxes is composed of the following: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (In thousands) United States $ 16,168 $ (19,129) $ 77,832 $ (57,769) Foreign 313,799 (8,847) 459,139 (141,400) Income (loss) before income taxes $ 329,967 $ (27,976) $ 536,971 $ (199,169)

Net Income (Loss) Per Share (Ta

Net Income (Loss) Per Share (Tables)	9 Months Ended
	Sep. 30, 2022
Earnings Per Share [Abstract]
Schedule of reconciliation between net income (loss) and the amounts used to compute basic and diluted net income (loss) per share and the weighted average shares outstanding used to compute basic and diluted net income (loss) per share	The following table is a reconciliation between net income (loss) and the amounts used to compute basic and diluted net income (loss) per share and the weighted average shares outstanding used to compute basic and diluted net income (loss) per share: Three Months Ended Nine Months Ended September 30, September 30, 2022 2021 2022 2021 (In thousands, except per share data) Numerator: Net income (loss) allocable to common stockholders $ 222,254 $ (28,597) $ 340,827 $ (176,552) Denominator: Weighted average number of shares outstanding: Basic 455,840 408,520 455,158 408,009 Restricted stock units(1) 20,591 — 19,662 — Diluted 476,431 408,520 474,820 408,009 Net income (loss) per share: Basic $ 0.49 $ (0.07) $ 0.75 $ (0.43) Diluted $ 0.47 $ (0.07) $ 0.72 $ (0.43) __________________________________ (1) We excluded restricted stock units of 0.2 million and 15.4 million for the three months ended September 30, 2022 and 2021, respectively, and 0.1 million and 15.0 million for the nine months ended September 30, 2022 and 2021, respectively, from the computations of diluted net income (loss) per share because the effect would have been anti-dilutive.

Additional Financial Informat_2

Additional Financial Information (Tables)	9 Months Ended
	Sep. 30, 2022
Additional Financial Information
Schedule of accrued liabilities	Accrued liabilities consisted of the following: September 30, December 31, (In thousands) Accrued liabilities: Exploration, development and production $ 54,901 $ 61,881 Revenue payable 21,830 31,986 Current asset retirement obligations 3,234 3,222 General and administrative expenses 23,886 27,980 Interest 28,800 31,117 Income taxes 105,963 69,392 Taxes other than income 1,547 2,854 Derivatives 6,311 19,302 Other 5,724 2,936 $ 252,196 $ 250,670
Schedule of changes in asset retirement obligations	The following table summarizes the changes in the Company's asset retirement obligations as of and during the nine months ended September 30, 2022: September 30, (In thousands) Asset retirement obligations: Beginning asset retirement obligations $ 325,459 Liabilities incurred during period 11,964 Liabilities settled during period (10,532) Revisions in estimated retirement obligations (65,552) Accretion expense 17,762 Ending asset retirement obligations $ 279,101
Schedule of other expenses, net incurred	Other expenses, net incurred during the period is comprised of the following: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (In thousands) (Gain) loss on disposal of inventory $ (821) $ (280) $ (536) $ 302 Loss on asset retirement obligations liability settlements — 58 620 444 Restructuring charges — (127) (4) 710 Other, net 603 543 (1,400) (453) Other expenses, net $ (218) $ 194 $ (1,320) $ 1,003

Business Segment Information (T

Business Segment Information (Tables)	9 Months Ended
	Sep. 30, 2022
Segment Reporting [Abstract]
Schedule of business segment information	Financial information for each area is presented below: Ghana(2) Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico(3) Corporate & Other Eliminations Total (In thousands) Three months ended September 30, 2022 Revenues and other income: Oil and gas revenue $ 296,980 $ 42,473 $ — $ 116,603 $ — $ — $ 456,056 Other income, net 1 — — 698 (82,537) 81,886 48 Total revenues and other income 296,981 42,473 — 117,301 (82,537) 81,886 456,104 Costs and expenses: Oil and gas production 23,911 11,921 — 26,540 — — 62,372 Facilities insurance modifications, net 494 — — — — — 494 Exploration expenses 9,459 1,071 2,182 2,674 1,829 — 17,215 General and administrative 3,967 1,991 2,624 2,804 44,577 (31,956) 24,007 Depletion, depreciation and amortization 65,288 7,741 143 32,701 440 — 106,313 Interest and other financing costs, net(1) 16,922 (595) (18,402) 2,785 29,086 — 29,796 Derivatives, net — — — — (113,842) — (113,842) Other expenses, net (101,457) (6,464) 145 (6,317) 33 113,842 (218) Total costs and expenses 18,584 15,665 (13,308) 61,187 (37,877) 81,886 126,137 Income (loss) before income taxes 278,397 26,808 13,308 56,114 (44,660) — 329,967 Income tax expense (benefit) 98,413 7,371 — (275) 2,204 — 107,713 Net income (loss) $ 179,984 $ 19,437 $ 13,308 $ 56,389 $ (46,864) $ — $ 222,254 Consolidated capital expenditures, net $ 40,871 $ 2,435 $ 114,339 $ 43,612 $ 1,834 $ — $ 203,091 Ghana(2) Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico(3) Corporate & Other Eliminations Total (In thousands) Nine months ended September 30, 2022 Revenues and other income: Oil and gas revenue $ 1,032,551 $ 261,442 $ — $ 441,446 $ — $ — $ 1,735,439 Gain on sale of assets — — — 471 — — 471 Other income, net 1 — — 1,726 340,768 (342,352) 143 Total revenues and other income 1,032,552 261,442 — 443,643 340,768 (342,352) 1,736,053 Costs and expenses: Oil and gas production 137,030 60,384 — 79,850 — — 277,264 Facilities insurance modifications, net 7,246 — — — — — 7,246 Exploration expenses 11,433 4,047 80,271 19,770 3,135 — 118,656 General and administrative 11,379 5,008 6,890 11,181 138,783 (98,817) 74,424 Depletion, depreciation and amortization 229,074 40,729 257 115,648 1,253 — 386,961 Interest and other financing costs, net(1) 46,208 (1,682) (46,903) 8,244 86,450 — 92,317 Derivatives, net — — — — 243,534 — 243,534 Other expenses, net 215,340 17,553 (1,200) 11,355 (834) (243,534) (1,320) Total costs and expenses 657,710 126,039 39,315 246,048 472,321 (342,351) 1,199,082 Income (loss) before income taxes 374,842 135,403 (39,315) 197,595 (131,553) (1) 536,971 Income tax expense (benefit) 133,193 55,420 — 2,828 4,703 — 196,144 Net income (loss) $ 241,649 $ 79,983 $ (39,315) $ 194,767 $ (136,256) $ (1) $ 340,827 Consolidated capital expenditures, net $ 32,814 $ 26,732 $ 261,755 $ 107,856 $ 4,545 $ — $ 433,702 As of September 30, 2022 Property and equipment, net $ 1,627,871 $ 385,442 $ 1,225,991 $ 881,990 $ 17,373 $ — $ 4,138,667 Total assets $ 3,211,263 $ 1,130,390 $ 1,727,997 $ 3,649,195 $ 18,987,516 $ (23,784,949) $ 4,921,412 ______________________________________ (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 reduction in Consolidated capital expenditures for the nine months ended September 30, 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 Consolidated capital expenditures for the nine months ended September 30, 2022. Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Three months ended September 30, 2021 Revenues and other income: Oil and gas revenue $ 67,247 $ 35,063 $ — $ 96,626 $ — $ — $ 198,936 Gain on sale of assets — — — — 1,538 — 1,538 Other income, net — — — 256 65,941 (66,131) 66 Total revenues and other income 67,247 35,063 — 96,882 67,479 (66,131) 200,540 Costs and expenses: Oil and gas production 10,490 13,029 — 26,797 — — 50,316 Facilities insurance modifications, net 1,555 — — — (1) — 1,554 Exploration expenses 89 2,089 7,081 13,975 748 — 23,982 General and administrative 3,165 581 2,980 4,177 39,464 (27,908) 22,459 Depletion, depreciation and amortization 20,958 5,999 15 37,551 391 — 64,914 Interest and other financing costs, net(1) 16,836 (446) (11,604) 3,446 18,641 — 26,873 Derivatives, net — — — — 38,224 — 38,224 Other expenses, net 34,382 3,229 (106) 648 265 (38,224) 194 Total costs and expenses 87,475 24,481 (1,634) 86,594 97,732 (66,132) 228,516 Income (loss) before income taxes (20,228) 10,582 1,634 10,288 (30,253) 1 (27,976) Income tax expense (benefit) (6,782) 5,758 — — 1,645 — 621 Net income (loss) $ (13,446) $ 4,824 $ 1,634 $ 10,288 $ (31,898) $ 1 $ (28,597) Consolidated capital expenditures, net $ 30,935 $ 20,351 $ 13,734 $ 21,188 $ (162) $ — $ 86,046 Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Nine months ended September 30, 2021 Revenues and other income: Oil and gas revenue $ 313,126 $ 147,424 $ — $ 298,905 $ — $ — $ 759,455 Gain on sale of assets — — — — 1,564 — 1,564 Other income, net 1 — — 1,028 347,866 (348,685) 210 Total revenues and other income 313,127 147,424 — 299,933 349,430 (348,685) 761,229 Costs and expenses: Oil and gas production 80,189 56,373 — 75,309 — — 211,871 Facilities insurance modifications, net 3,495 — — — — — 3,495 Exploration expenses 164 4,666 10,812 20,541 5,269 — 41,452 General and administrative 8,636 2,883 7,677 12,620 129,108 (94,296) 66,628 Depletion, depreciation and amortization 132,232 34,474 46 124,598 1,266 — 292,616 Interest and other financing costs, net(1) 36,890 (1,218) (33,816) 12,307 78,348 (1,784) 90,727 Derivatives, net — — — — 252,606 — 252,606 Other expenses, net 193,370 34,096 (2,348) 26,185 2,306 (252,606) 1,003 Total costs and expenses 454,976 131,274 (17,629) 271,560 468,903 (348,686) 960,398 Income (loss) before income taxes (141,849) 16,150 17,629 28,373 (119,473) 1 (199,169) Income tax expense (benefit) (48,770) 19,957 — — 6,196 — (22,617) Net income (loss) $ (93,079) $ (3,807) $ 17,629 $ 28,373 $ (125,669) $ 1 $ (176,552) Consolidated capital expenditures, net $ 61,570 $ 51,444 $ 169,158 $ 65,674 $ 5,564 $ — $ 353,410 As of September 30, 2021 Property and equipment, net $ 1,226,513 $ 447,795 $ 822,013 $ 925,384 $ 21,192 $ — $ 3,442,897 Total assets $ 1,297,303 $ 854,530 $ 1,329,267 $ 3,216,368 $ 14,315,531 $ (16,859,275) $ 4,153,724 ______________________________________ (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. Nine Months Ended September 30, 2022 2021 (In thousands) Consolidated capital expenditures: Consolidated Statements of Cash Flows - Investing activities: Oil and gas assets $ 543,349 $ 377,850 Acquisition of oil and gas properties 21,205 — Proceeds on sale of assets (118,703) (5,327) Adjustments: Changes in capital accruals 1,511 (16,523) Exploration expense, excluding unsuccessful well costs and leasehold impairments(1) 35,570 24,680 Capitalized interest (57,489) (31,956) Other 8,259 4,686 Total consolidated capital expenditures, net $ 433,702 $ 353,410 ______________________________________ (1) Unsuccessful well costs and leasehold impairments are included in oil and gas assets when incurred.

Organization (Details)

Organization (Details)	9 Months Ended
	Sep. 30, 2022 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable geographic areas	4

Accounting Policies - Cash, Cas

Accounting Policies - Cash, Cash Equivalents, and Restricted Cash (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021	Sep. 30, 2021	Dec. 31, 2020
Accounting Policies [Abstract]
Cash and cash equivalents	$ 231,565	$ 131,620
Restricted cash - current	27	42,971
Restricted cash - long-term	305	305
Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows	$ 231,897	$ 174,896	$ 154,842	$ 149,764

Accounting Policies - Narrative

Accounting Policies - Narrative (Details) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2022 USD ($)	Sep. 30, 2022 USD ($)	May 31, 2022 USD ($)	Mar. 31, 2022	Dec. 31, 2021 USD ($)	Oct. 31, 2021	Mar. 31, 2021	Apr. 30, 2019
Restricted Cash
Restricted cash - current	$ 27	$ 27			$ 42,971
Materials and supplies inventory	129,000	129,000			149,500
Hydrocarbons inventory	21,300	$ 21,300			$ 15,700
Inventory sold	$ 14,900
Facility
Restricted Cash
Net leverage ratio	2.50	2.50		2.50
Facility Interest Or Senior Notes Plus The Corporate Revolver
Restricted Cash
Period for contractual future payments (in months)		6 months
Restricted cash - current			$ 59,100
7.125% Senior Notes | Senior Notes
Restricted Cash
Interest rate (as a percent)								7.125%
7.750% Senior Notes | Senior Notes
Restricted Cash
Interest rate (as a percent)						7.75%
7.500% Senior Notes | Senior Notes
Restricted Cash
Interest rate (as a percent)							7.50%

Accounting Policies - Summary o

Accounting Policies - Summary of Oil and Gas Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Disaggregation of Revenue [Line Items]
Provisional oil sales contracts	$ 110,262	$ (36,130)	$ (257,112)	$ (259,289)
Oil and gas revenue	456,056	198,936	1,735,439	759,455
Oil and gas revenue
Disaggregation of Revenue [Line Items]
Provisional oil sales contracts	(3,580)	2,094	(13,578)	(6,683)
Oil and gas revenue	456,056	198,936	1,735,439	759,455
Equatorial Guinea
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	41,178	34,247	263,532	145,378
Ghana
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	301,855	65,969	1,044,039	321,855
U.S. Gulf of Mexico
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 116,603	$ 96,626	$ 441,446	$ 298,905

Acquisitions and Divestitures (

Acquisitions and Divestitures (Details) $ in Thousands	1 Months Ended			3 Months Ended				9 Months Ended
	Sep. 30, 2022 USD ($) transaction	Jun. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Sep. 30, 2022 USD ($)	Jun. 30, 2022 USD ($) well	Mar. 31, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	May 31, 2022	Oct. 31, 2021
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Proceeds on sale of assets								$ 118,703	$ 5,327
Gain on sale of assets				$ 0			$ 1,538	$ 471	$ 1,564
Block G Petroleum | Block G Ceiba Field And Okume Complex
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Number of development wells | well					3
Block G Petroleum | Block S Offshore Equatorial Guinea
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Number of exploration wells | well					1
Winterfell Green Canyon Blocks
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Number of transactions | transaction	2
Winterfell Green Canyon Blocks | Green Canyon Blocks 943, 944, 987, 988, 899 and 900
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Payments to acquire businesses, gross	$ 6,600		$ 9,600
Winterfell Green Canyon Blocks | Green Canyon Blocks 943, 944, 987 and 988
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Participating interest percentage after acquired interest (as a percent)	25%			25%				25%
Participating interest percentage acquired (as a percent)	3.20%		5.50%
Winterfell Green Canyon Blocks | Green Canyon Blocks 899 and 900
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Participating interest percentage after acquired interest (as a percent)	37.80%			37.80%				37.80%
Participating interest percentage acquired (as a percent)	1.40%		1.50%
Jubilee Unit | Deepwater Tano Block Joint Operating Agreement
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Participating interest after pre-emption (as a percent)			38.60%			38.60%
Ultimate interest upon full exercise of pre-emption rights (as a percent)	38.30%			38.30%				38.30%
Jubilee Unit | Anadarko WCTP
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Participating interest percentage after acquired interest (as a percent)											42.10%
TEN fields | Deepwater Tano Block Joint Operating Agreement
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Participating interest after pre-emption (as a percent)			20.40%			20.40%
Ultimate interest upon full exercise of pre-emption rights (as a percent)	19.80%			19.80%				19.80%
TEN fields | Anadarko WCTP
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Participating interest percentage after acquired interest (as a percent)											28.10%
Jubilee Unit Area And Ten Fields | Tullow
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Proceeds on sale of assets			$ 118,200					$ 118,200
Oil and gas property, net reduction from divestiture						$ 175,500
Gain on sale of assets								$ 0
Kodiak Field | Marubeni
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Participating interest percentage after acquired interest (as a percent)		35%			35%
Participating interest percentage acquired (as a percent)		5.90%
Payments to acquire businesses, gross		$ 21,200
Participating interest (as a percent)										29.10%
Additional deferred payments		7,800
Business combination, consideration transferred		29,000
Initial purchase price		38,300
Business combination, purchase price adjustments		9,300
Fair value of identifiable assets acquired and liabilities assumed		$ 27,100			$ 27,100

Joint Interest Billings and L_2

Joint Interest Billings and Long-term Receivables (Details) $ in Thousands		1 Months Ended	3 Months Ended				9 Months Ended
	Sep. 30, 2022 USD ($)	Feb. 28, 2019 agreement	Sep. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Aug. 31, 2021 USD ($)
Oil and Gas Joint Interest Billing Receivables [Line Items]
Joint interest billings, net	$ 40,643		$ 40,643		$ 36,908		$ 40,643
Long-term receivables	201,196		201,196		191,150		201,196
BP Operator
Oil and Gas Joint Interest Billing Receivables [Line Items]
Long-term investments and receivables, net									$ 200,200
Settlement of payment obligation of capital expenditures				$ 67,800	132,400
National Oil Companies of Mauritania And Senegal | Carry Advance Agreements
Oil and Gas Joint Interest Billing Receivables [Line Items]
Long-term receivables	179,300		179,300		145,200		179,300
Number of agreements | agreement		2
Share of development costs to be financed, up to	240,000
Interest income, long-term notes receivable			2,500			$ 1,800	6,800	$ 5,400
Greater Tortue FPSO | BP Operator
Oil and Gas Joint Interest Billing Receivables [Line Items]
Contract liability, noncurrent	200,200		200,200				200,200		$ 200,200
TEN Discoveries | GNPC
Oil and Gas Joint Interest Billing Receivables [Line Items]
Joint interest billings, net	7,900		7,900		7,900		7,900
Long-term receivables	$ 21,100		$ 21,100		$ 20,900		$ 21,100
TEN Discoveries | GNPC
Oil and Gas Joint Interest Billing Receivables [Line Items]
GNPC's paying interest (as a percent)							5%

Property and Equipment (Details

Property and Equipment (Details) - USD ($) $ in Thousands	3 Months Ended				9 Months Ended
	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Oil and gas properties:
Proved properties	$ 7,050,725				$ 7,050,725		$ 6,725,453
Unproved properties	434,574				434,574		451,454
Total oil and gas properties	7,485,299				7,485,299		7,176,907
Accumulated depletion	(3,352,337)				(3,352,337)		(2,999,584)
Oil and gas properties, net	4,132,962				4,132,962		4,177,323
Other property	60,419				60,419		58,598
Accumulated depreciation	(54,714)				(54,714)		(51,934)
Other property, net	5,705				5,705		6,664
Property and equipment, net	4,138,667			$ 3,442,897	4,138,667	$ 3,442,897	$ 4,183,987
Depletion expense	$ 100,000			$ 58,800	366,400	$ 274,600
Capitalized costs written off					62,818
BirAllah and Orca Discoveries
Oil and gas properties:
Capitalized costs written off		$ 64,200
Jubilee Unit Area And Ten Fields | Tullow
Oil and gas properties:
Oil and gas property, net reduction from divestiture			$ 175,500
Kodiak Field, Block G Equatorial Guinea And Winterfell
Oil and gas properties:
Oil and gas property, net addition from acquisition and licenses extension					$ 53,100

Suspended Well Costs - Summary

Suspended Well Costs - Summary of Suspended Well Costs (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2022 USD ($) project	Dec. 31, 2021 USD ($) project
Reconciliation of capitalized exploratory well costs on completed wells
Beginning balance	$ 218,180
Additions to capitalized exploratory well costs pending the determination of proved reserves	22,037
Reclassification due to determination of proved reserves	0
Capitalized exploratory well costs charged to expense	(62,818)
Ending balance	177,399
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	$ 20,903
Exploratory well costs capitalized for a period of one to three years	65,890	30,389
Exploratory well costs capitalized for a period of four to six years	111,509	166,888
Ending balance	$ 177,399	$ 218,180
Number of projects that have exploratory well costs that have been capitalized for a period greater than one year | project	3	3

Suspended Well Costs - Narrativ

Suspended Well Costs - Narrative (Details) $ in Thousands	1 Months Ended		3 Months Ended	9 Months Ended
	Jul. 31, 2021	Sep. 30, 2019 km	Jun. 30, 2022 USD ($)	Sep. 30, 2022 USD ($)
Capitalized Contract Cost [Line Items]
Capitalized costs written off				$ 62,818
BirAllah and Orca Discoveries
Capitalized Contract Cost [Line Items]
Capitalized costs written off			$ 64,200
Yakaar and Teranga Discoveries
Capitalized Contract Cost [Line Items]
Distance from Yakaar-2 well to Yakaar-1 exploration well | km		9
Additional term from exploration license extension	3 years

Debt - Schedule of Instruments

Debt - Schedule of Instruments (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021	Oct. 31, 2021	Mar. 31, 2021	Apr. 30, 2019
Line of Credit Facility [Line Items]
Outstanding debt principal	$ 2,352,500	$ 2,675,000
Unamortized deferred financing costs and discounts	(46,731)	(54,505)
Total debt, net	2,305,769	2,620,495
Less: Current maturities of long-term debt	(30,000)	(30,000)
Long-term debt, net	2,275,769	2,590,495
Facility | Revolving credit facility
Line of Credit Facility [Line Items]
Outstanding debt principal	700,000	1,000,000
7.125% Senior Notes | Senior Notes
Line of Credit Facility [Line Items]
Interest rate (as a percent)					7.125%
Outstanding debt principal	650,000	650,000
7.750% Senior Notes | Senior Notes
Line of Credit Facility [Line Items]
Interest rate (as a percent)			7.75%
Outstanding debt principal	400,000	400,000
7.500% Senior Notes | Senior Notes
Line of Credit Facility [Line Items]
Interest rate (as a percent)				7.50%
Outstanding debt principal	450,000	450,000
GoM Term Loan | Secured Debt
Line of Credit Facility [Line Items]
Outstanding debt principal	152,500	$ 175,000
Less: Current maturities of long-term debt	$ (30,000)

Debt - Facility (Details)

Debt - Facility (Details) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Jun. 30, 2021 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Oct. 31, 2022 USD ($)	May 31, 2022 USD ($)	Mar. 31, 2022	Dec. 31, 2021 USD ($)	Apr. 30, 2019
Debt Instrument [Line Items]
Loss on extinguishment of debt	$ 0	$ 0		$ 192	$ 15,223
Restricted cash - current	$ 27			$ 27					$ 42,971
Facility
Debt Instrument [Line Items]
Net leverage ratio	2.50			2.50				2.50
Facility Interest Or Senior Notes Plus The Corporate Revolver
Debt Instrument [Line Items]
Interval period for payment of interest (in months)				6 months
Restricted cash - current							$ 59,100
7.125% Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)										7.125%
Revolving credit facility | Facility
Debt Instrument [Line Items]
Amount outstanding	$ 700,000			$ 700,000
Undrawn availability	$ 550,000			550,000
Principal repayments				300,000
Proceeds from the Tullow pre-emption transaction				$ 100,000
Loss on extinguishment of debt			$ 15,200
Revolving credit facility | Facility | Subsequent Event
Debt Instrument [Line Items]
Maximum borrowing capacity						$ 1,240,000

Debt - Corporate Revolver (Deta

Debt - Corporate Revolver (Details) - Corporate Revolver - Revolving credit facility - USD ($) $ in Millions	Mar. 31, 2022	Sep. 30, 2022	Mar. 30, 2022
Debt Instrument [Line Items]
Undrawn availability	$ 250	$ 250	$ 400
Cash sweep percent (as a percent)	50%
Deferred financing costs		6.1
Amount outstanding		$ 0
Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Debt Instrument [Line Items]
Applicable margin (as a percent)	7%

Debt - Senior Notes (Details)

Debt - Senior Notes (Details) - USD ($) $ in Thousands	1 Months Ended			9 Months Ended
	Oct. 31, 2021	Mar. 31, 2021	Apr. 30, 2019	Sep. 30, 2022	Sep. 30, 2021
Debt Instrument [Line Items]
Repayments of debt				$ 322,500	$ 400,000
Senior Notes | 7.125% Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)			7.125%
Debt, face amount			$ 650,000
Proceeds from debt, net of issuance costs			$ 640,000
Senior Notes | 7.875% Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)			7.875%
Senior Notes | 7.750% Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)	7.75%
Debt, face amount	$ 400,000
Proceeds from debt, net of issuance costs	395,000
Senior Notes | 7.500% Senior Notes
Debt Instrument [Line Items]
Interest rate (as a percent)		7.50%
Debt, face amount		$ 450,000
Proceeds from debt, net of issuance costs		$ 444,400
Senior Notes | Bridge Notes
Debt Instrument [Line Items]
Repayments of debt	$ 400,000

Debt - GoM Term Loan (Details)

Debt - GoM Term Loan (Details) - USD ($) $ in Thousands	1 Months Ended
	Sep. 30, 2020	Sep. 30, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Current maturities of long-term debt		$ 30,000	$ 30,000
Outstanding debt principal		$ 2,352,500	2,675,000
GoM Term Loan | Secured Debt
Debt Instrument [Line Items]
Debt term (in years)	5 years
Debt, face amount	$ 200,000
Net proceeds from issuance of secured debt	197,700
Additional incremental commitments	$ 100,000
Debt instrument, interest rate (as a percent)		6.60%
Current maturities of long-term debt		$ 30,000
Outstanding debt principal		$ 152,500	$ 175,000

Debt - Principal Debt Repayment

Debt - Principal Debt Repayments (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Scheduled maturities of debt during the five year period and thereafter
Total	$ 2,352,500	$ 2,675,000
2022	7,500
2023	30,000
2024	30,000
2025	254,011
2026	1,002,418
Thereafter	$ 1,028,571

Debt - Interest and Other Finan

Debt - Interest and Other Financing Costs, Net (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Debt Disclosure [Abstract]
Interest expense	$ 45,448	$ 36,055	$ 131,626	$ 103,229
Amortization—deferred financing costs	2,577	2,597	7,838	7,788
Loss on extinguishment of debt	0	0	192	15,223
Capitalized interest	(22,163)	(12,252)	(57,489)	(31,956)
Deferred interest	4	(600)	(1,436)	(724)
Interest income	(2,956)	(2,237)	(7,840)	(8,309)
Other, net	6,886	3,310	19,426	5,476
Interest and other financing costs, net	$ 29,796	$ 26,873	$ 92,317	$ 90,727

Derivative Financial Instrume_3

Derivative Financial Instruments - Oil Derivative Contracts (Details)	1 Months Ended	9 Months Ended
	Oct. 31, 2022 $ / bbl MBbls	Sep. 30, 2022 $ / bbl MBbls
Dated Brent | Term October 2022 To December 2022 | Three-way collars
Derivative Financial Instruments
Volume | MBbls		1,125
Weighted Average Price per Bbl
Net deferred premium payable/(receivable) (usd per bbl)		0.64
Sold Put (usd per bbl)		43.33
Floor (usd per bbl)		56.67
Ceiling (usd per bbl)		76.91
Dated Brent | Term October 2022 To December 2022 | Two-way collars
Derivative Financial Instruments
Volume | MBbls		1,500
Weighted Average Price per Bbl
Net deferred premium payable/(receivable) (usd per bbl)		1.22
Sold Put (usd per bbl)		0
Floor (usd per bbl)		62.50
Ceiling (usd per bbl)		83.33
Dated Brent | Term October 2022 To December 2022 | Sold calls
Derivative Financial Instruments
Volume | MBbls		395
Weighted Average Price per Bbl
Net deferred premium payable/(receivable) (usd per bbl)		0
Sold Put (usd per bbl)		0
Floor (usd per bbl)		0
Ceiling (usd per bbl)		60
Dated Brent | Term January 2023 To December 2023 | Three-way collars
Derivative Financial Instruments
Volume | MBbls		4,000
Weighted Average Price per Bbl
Net deferred premium payable/(receivable) (usd per bbl)		1.21
Sold Put (usd per bbl)		48.75
Floor (usd per bbl)		70
Ceiling (usd per bbl)		106.38
Dated Brent | Term January 2023 To December 2023 | Three-way collars | Subsequent Event
Derivative Financial Instruments
Volume | MBbls	1,000
Weighted Average Price per Bbl
Sold Put (usd per bbl)	50
Floor (usd per bbl)	75
Ceiling (usd per bbl)	110
Dated Brent | Term January 2023 To December 2023 | Two-way collars
Derivative Financial Instruments
Volume | MBbls		2,000
Weighted Average Price per Bbl
Net deferred premium payable/(receivable) (usd per bbl)		2.50
Sold Put (usd per bbl)		0
Floor (usd per bbl)		75
Ceiling (usd per bbl)		125
Dated Brent | Term January 2023 To December 2023 | Two-way collars | Subsequent Event
Derivative Financial Instruments
Volume | MBbls	2,000
Weighted Average Price per Bbl
Floor (usd per bbl)	70
Ceiling (usd per bbl)	110
NYMEX WTI | Term October 2022 To December 2022 | Three-way collars
Derivative Financial Instruments
Volume | MBbls		250
Weighted Average Price per Bbl
Net deferred premium payable/(receivable) (usd per bbl)		1.45
Sold Put (usd per bbl)		50
Floor (usd per bbl)		65
Ceiling (usd per bbl)		85

Derivative Financial Instrume_4

Derivative Financial Instruments - Derivative Instruments and Gain/(Loss) from Derivatives (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Derivative instruments, Balance Sheet Location
Derivatives assets—current	$ 11,879	$ 5,689
Derivatives assets—long-term	8,646	1,026
Derivatives liabilities—current	(37,477)	(65,879)
Derivatives liabilities—long-term	(2,147)	(6,298)
Derivatives not designated as hedging instruments
Derivative instruments, Balance Sheet Location
Total derivatives not designated as hedging instruments	(19,099)	(66,315)
Derivatives not designated as hedging instruments | Commodity
Derivative instruments, Balance Sheet Location
Derivatives assets—current	11,879	5,689
Derivatives assets—long-term	8,646	1,026
Derivatives liabilities—current	(37,477)	(65,879)
Derivatives liabilities—long-term	(2,147)	(6,298)
Derivatives not designated as hedging instruments | Provisional oil sales
Derivative instruments, Balance Sheet Location
Derivatives assets—current	$ 0	$ (853)

Derivative Financial Instrume_5

Derivative Financial Instruments - Location of Gain (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Derivative instruments, Location of Gain/(Loss)
Amount of Gain/(Loss)	$ 110,262	$ (36,130)	$ (257,112)	$ (259,289)
Provisional oil sales | Oil and gas revenue
Derivative instruments, Location of Gain/(Loss)
Amount of Gain/(Loss)	(3,580)	2,094	(13,578)	(6,683)
Commodity | Derivatives, net
Derivative instruments, Location of Gain/(Loss)
Amount of Gain/(Loss)	$ 113,842	$ (38,224)	$ (243,534)	$ (252,606)

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021	Oct. 31, 2021	Mar. 31, 2021	Apr. 30, 2019
Liabilities:
Impairment of long-lived assets	$ 0	$ 0	$ 0	$ 0
Carrying Value
Liabilities:
Long-term debt	2,338,997		2,338,997		$ 2,659,595
Fair Value
Liabilities:
Long-term debt	2,060,124		2,060,124		2,618,703
7.125% Senior Notes | Senior Notes
Liabilities:
Interest rate (as a percent)								7.125%
7.125% Senior Notes | Senior Notes | Carrying Value
Liabilities:
Long-term debt	645,409		645,409		644,572
7.125% Senior Notes | Senior Notes | Fair Value
Liabilities:
Long-term debt	534,034		534,034		632,587
7.750% Senior Notes | Senior Notes
Liabilities:
Interest rate (as a percent)						7.75%
7.750% Senior Notes | Senior Notes | Carrying Value
Liabilities:
Long-term debt	395,697		395,697		395,131
7.750% Senior Notes | Senior Notes | Fair Value
Liabilities:
Long-term debt	320,992		320,992		386,428
7.500% Senior Notes | Senior Notes
Liabilities:
Interest rate (as a percent)							7.50%
7.500% Senior Notes | Senior Notes | Carrying Value
Liabilities:
Long-term debt	445,391		445,391		444,892
7.500% Senior Notes | Senior Notes | Fair Value
Liabilities:
Long-term debt	352,598		352,598		424,688
GoM Term Loan | Secured Debt | Carrying Value
Liabilities:
Long-term debt	152,500		152,500		175,000
GoM Term Loan | Secured Debt | Fair Value
Liabilities:
Long-term debt	152,500		152,500		175,000
Facility | Facility | Carrying Value
Liabilities:
Long-term debt	700,000		700,000		1,000,000
Facility | Facility | Fair Value
Liabilities:
Long-term debt	700,000		700,000		1,000,000
Recurring basis
Liabilities:
Total derivatives not designated as hedging instruments	(19,099)		(19,099)		(66,315)
Recurring basis | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Total derivatives not designated as hedging instruments	0		0		0
Recurring basis | Significant Other Observable Inputs (Level 2)
Liabilities:
Total derivatives not designated as hedging instruments	(19,099)		(19,099)		(66,315)
Recurring basis | Significant Unobservable Inputs (Level 3)
Liabilities:
Total derivatives not designated as hedging instruments	0		0		0
Recurring basis | Commodity derivatives
Assets:
Derivative asset, fair value	20,525		20,525		6,715
Liabilities:
Derivative liability, fair value	(39,624)		(39,624)		(72,177)
Recurring basis | Commodity derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivative asset, fair value	0		0		0
Liabilities:
Derivative liability, fair value	0		0		0
Recurring basis | Commodity derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivative asset, fair value	20,525		20,525		6,715
Liabilities:
Derivative liability, fair value	(39,624)		(39,624)		(72,177)
Recurring basis | Commodity derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivative asset, fair value	0		0		0
Liabilities:
Derivative liability, fair value	0		0		0
Recurring basis | Provisional oil sales
Assets:
Derivative asset, fair value	0		0		(853)
Recurring basis | Provisional oil sales | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivative asset, fair value	0		0		0
Recurring basis | Provisional oil sales | Significant Other Observable Inputs (Level 2)
Assets:
Derivative asset, fair value	0		0		(853)
Recurring basis | Provisional oil sales | Significant Unobservable Inputs (Level 3)
Assets:
Derivative asset, fair value	$ 0		$ 0		$ 0

Equity-based Compensation - Nar

Equity-based Compensation - Narrative (Details) - LTIP - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense recognized	$ 8.8	$ 8.1	$ 25.9	$ 24
Tax benefit	1.5	1.5	4.4	4.5
Net tax shortfall related to equity-based compensation	0	1.5	0.7	6.3
Fair value of awards vested	$ 0.5	$ 1	$ 21.9	$ 9.4
Vesting period (in years)			3 years
Number of shares remaining available for grant (in shares)	6		6
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense not yet recognized	$ 28.5		$ 28.5
Weighted average period over which compensation expense is to be recognized (in years)			1 year 9 months 10 days
Market/Service Vesting Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grant date fair value of awards granted (in dollars per share)			$ 6.97
Market/Service Vesting Restricted Stock Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting percentage of the awards granted (up to)			0%
Grant date fair value of awards granted (in dollars per share)			$ 1.06
Expected volatility			50%
Risk-free interest rate (as a percent)			0.20%
Market/Service Vesting Restricted Stock Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting percentage of the awards granted (up to)			200%
Grant date fair value of awards granted (in dollars per share)			$ 12.33
Expected volatility			104.80%
Risk-free interest rate (as a percent)			2.50%

Equity-based Compensation - Sch

Equity-based Compensation - Schedule of Awards (Details) - LTIP shares in Thousands	9 Months Ended
	Sep. 30, 2022 $ / shares shares
Service Vesting Restricted Stock Units
Outstanding unvested awards activity
Outstanding at the beginning of the period (in shares) | shares	4,696
Granted (in shares) | shares	2,793
Forfeited (in shares) | shares	(145)
Vested (in shares) | shares	(2,413)
Outstanding at the end of the period (in shares) | shares	4,931
Weighted-Average Grant-Date Fair Value
Outstanding at beginning of the period (in dollars per share)	$ 3.88
Granted (in dollars per share)	4.70
Forfeited (in dollars per share)	3.91
Vested (in dollars per share)	4.20
Outstanding at the end of the period (in dollars per share)	$ 4.18
Market/Service Vesting Restricted Stock Units
Outstanding unvested awards activity
Outstanding at the beginning of the period (in shares) | shares	11,233
Granted (in shares) | shares	3,378
Forfeited (in shares) | shares	(389)
Vested (in shares) | shares	(2,175)
Outstanding at the end of the period (in shares) | shares	12,047
Weighted-Average Grant-Date Fair Value
Outstanding at beginning of the period (in dollars per share)	$ 5.28
Granted (in dollars per share)	6.97
Forfeited (in dollars per share)	6.19
Vested (in dollars per share)	5.98
Outstanding at the end of the period (in dollars per share)	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)	$ 12.33
Vesting percentage of the awards granted (as a percent)	200%
Percent threshold target for grants and forfeitures (as a percent)	100%

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Income Taxes
Decrease in deferred tax liability			$ 81.3
Decrease from other reconciling items			$ 36.7
Effective tax rate (as a percent)	33%	2%	37%	11%
Statutory tax rate (as a percent)			21%	21%
Ghanaian and Equatorial Guinean
Income Taxes
Statutory tax rate (as a percent)			35%	35%
Foreign
Income Taxes
Statutory tax rate (as a percent)			0%	0%
Tullow
Income Taxes
Decrease from pre-emption transaction			$ 44.6

Income Taxes - Schedule of Inco

Income Taxes - Schedule of Income (Loss) Before Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Income Taxes
Income (loss) before income taxes	$ 329,967	$ (27,976)	$ 536,971	$ (199,169)
United States
Income Taxes
Income (loss) before income taxes	16,168	(19,129)	77,832	(57,769)
Foreign
Income Taxes
Income (loss) before income taxes	$ 313,799	$ (8,847)	$ 459,139	$ (141,400)

Net Income (Loss) Per Share (De

Net Income (Loss) Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Numerator:
Net income (loss) allocable to common stockholders	$ 222,254	$ 117,173	$ 1,400	$ (28,597)	$ (57,187)	$ (90,768)	$ 340,827	$ (176,552)
Weighted average number of shares outstanding:
Basic (in shares)	455,840			408,520			455,158	408,009
Restricted stock units (in shares)	20,591			0			19,662	0
Diluted (in shares)	476,431			408,520			474,820	408,009
Net income (loss) per share:
Basic (in dollars per share)	$ 0.49			$ (0.07)			$ 0.75	$ (0.43)
Diluted (in dollars per share)	$ 0.47			$ (0.07)			$ 0.72	$ (0.43)
Outstanding restricted stock units excluded from the computations of diluted net income per share (in shares)	200			15,400			100	15,000

Commitments and Contingencies (

Commitments and Contingencies (Details) $ in Millions	9 Months Ended
	Sep. 30, 2022 USD ($) well	Dec. 31, 2021 USD ($)	Aug. 31, 2021 USD ($)
BP Operator | Greater Tortue FPSO
Operating Leased Assets [Line Items]
Contract liability, noncurrent	$ 200.2		$ 200.2
Equatorial Guinea
Operating Leased Assets [Line Items]
Number of development wells | well	3
Number of exploration wells | well	1
U.S. Gulf of Mexico | Bureau of Ocean Energy Management | Surety Bond
Operating Leased Assets [Line Items]
Required performance bonds	$ 203.7	$ 195.5
U.S. Gulf of Mexico | Third Party | Surety Bond
Operating Leased Assets [Line Items]
Required performance bonds	$ 9.7	$ 3.5

Additional Financial Informat_3

Additional Financial Information - Schedule of Accrued Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2022	Dec. 31, 2021
Accrued liabilities:
Exploration, development and production	$ 54,901	$ 61,881
Revenue payable	21,830	31,986
Current asset retirement obligations	3,234	3,222
General and administrative expenses	23,886	27,980
Interest	28,800	31,117
Income taxes	105,963	69,392
Taxes other than income	1,547	2,854
Derivatives	6,311	19,302
Other	5,724	2,936
Accrued liabilities	$ 252,196	$ 250,670

Additional Financial Informat_4

Additional Financial Information - Schedule of Changes in Asset Retirement Obligations (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2022 USD ($)
Asset retirement obligations:
Beginning asset retirement obligations	$ 325,459
Liabilities incurred during period	11,964
Liabilities settled during period	(10,532)
Revisions in estimated retirement obligations	(65,552)
Accretion expense	17,762
Ending asset retirement obligations	$ 279,101

Additional Financial Informat_5

Additional Financial Information - Narrative (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2022 USD ($)
Lessee, Lease, Description [Line Items]
Liabilities settled during period	$ 10,532
Revisions in estimated retirement obligations	(65,552)
Tullow
Lessee, Lease, Description [Line Items]
Liabilities settled during period	10,000
Equatorial Guinea
Lessee, Lease, Description [Line Items]
Revisions in estimated retirement obligations	$ 66,200

Additional Financial Informat_6

Additional Financial Information - Other Expenses, Net (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Additional Financial Information
(Gain) loss on disposal of inventory	$ (821)	$ (280)	$ (536)	$ 302
Loss on asset retirement obligations liability settlements	0	58	620	444
Restructuring charges	0	(127)	(4)	710
Other, net	603	543	(1,400)	(453)
Other expenses, net	$ (218)	$ 194	$ (1,320)	$ 1,003

Business Segment Information -

Business Segment Information - Narrative (Details)	9 Months Ended
	Sep. 30, 2022 segment
Segment Reporting [Abstract]
Number of reportable segments	4

Business Segment Information _2

Business Segment Information - Business Segment Information (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended						9 Months Ended
	Mar. 31, 2022	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Segment Reporting Information [Line Items]
Oil and gas revenue		$ 456,056			$ 198,936			$ 1,735,439	$ 759,455
Gain on sale of assets		0			1,538			471	1,564
Other income, net		48			66			143	210
Total revenues and other income		456,104			200,540			1,736,053	761,229
Oil and gas production		62,372			50,316			277,264	211,871
Facilities insurance modifications, net		494			1,554			7,246	3,495
Exploration expenses		17,215			23,982			118,656	41,452
General and administrative		24,007			22,459			74,424	66,628
Depletion, depreciation and amortization		106,313			64,914			386,961	292,616
Impairment of long-lived assets		0			0			0	0
Interest and other financing costs, net		29,796			26,873			92,317	90,727
Derivatives, net		(113,842)			38,224			243,534	252,606
Other expenses, net		(218)			194			(1,320)	1,003
Total costs and expenses		126,137			228,516			1,199,082	960,398
Income (loss) before income taxes		329,967			(27,976)			536,971	(199,169)
Income tax expense (benefit)		107,713			621			196,144	(22,617)
Net income (loss)		222,254	$ 117,173	$ 1,400	(28,597)	$ (57,187)	$ (90,768)	340,827	(176,552)
Consolidated capital expenditures, net		203,091			86,046			433,702	353,410
Property and equipment, net		4,138,667			3,442,897			4,138,667	3,442,897	$ 4,183,987
Total assets		4,921,412			4,153,724			4,921,412	4,153,724	$ 4,940,651
Proceeds on sale of assets								118,703	5,327
Jubilee Unit Area And Ten Fields | Tullow
Segment Reporting Information [Line Items]
Gain on sale of assets								0
Proceeds on sale of assets	$ 118,200							118,200
Operating Segments | Ghana
Segment Reporting Information [Line Items]
Oil and gas revenue		296,980			67,247			1,032,551	313,126
Gain on sale of assets					0			0	0
Other income, net		1			0			1	1
Total revenues and other income		296,981			67,247			1,032,552	313,127
Oil and gas production		23,911			10,490			137,030	80,189
Facilities insurance modifications, net		494			1,555			7,246	3,495
Exploration expenses		9,459			89			11,433	164
General and administrative		3,967			3,165			11,379	8,636
Depletion, depreciation and amortization		65,288			20,958			229,074	132,232
Interest and other financing costs, net		16,922			16,836			46,208	36,890
Derivatives, net		0			0			0	0
Other expenses, net		(101,457)			34,382			215,340	193,370
Total costs and expenses		18,584			87,475			657,710	454,976
Income (loss) before income taxes		278,397			(20,228)			374,842	(141,849)
Income tax expense (benefit)		98,413			(6,782)			133,193	(48,770)
Net income (loss)		179,984			(13,446)			241,649	(93,079)
Consolidated capital expenditures, net		40,871			30,935			32,814	61,570
Property and equipment, net		1,627,871			1,226,513			1,627,871	1,226,513
Total assets		3,211,263			1,297,303			3,211,263	1,297,303
Operating Segments | Equatorial Guinea
Segment Reporting Information [Line Items]
Oil and gas revenue		42,473			35,063			261,442	147,424
Gain on sale of assets					0			0	0
Other income, net		0			0			0	0
Total revenues and other income		42,473			35,063			261,442	147,424
Oil and gas production		11,921			13,029			60,384	56,373
Facilities insurance modifications, net		0			0			0	0
Exploration expenses		1,071			2,089			4,047	4,666
General and administrative		1,991			581			5,008	2,883
Depletion, depreciation and amortization		7,741			5,999			40,729	34,474
Interest and other financing costs, net		(595)			(446)			(1,682)	(1,218)
Derivatives, net		0			0			0	0
Other expenses, net		(6,464)			3,229			17,553	34,096
Total costs and expenses		15,665			24,481			126,039	131,274
Income (loss) before income taxes		26,808			10,582			135,403	16,150
Income tax expense (benefit)		7,371			5,758			55,420	19,957
Net income (loss)		19,437			4,824			79,983	(3,807)
Consolidated capital expenditures, net		2,435			20,351			26,732	51,444
Property and equipment, net		385,442			447,795			385,442	447,795
Total assets		1,130,390			854,530			1,130,390	854,530
Operating Segments | Mauritania/Senegal
Segment Reporting Information [Line Items]
Oil and gas revenue		0			0			0	0
Gain on sale of assets					0			0	0
Other income, net		0			0			0	0
Total revenues and other income		0			0			0	0
Oil and gas production		0			0			0	0
Facilities insurance modifications, net		0			0			0	0
Exploration expenses		2,182			7,081			80,271	10,812
General and administrative		2,624			2,980			6,890	7,677
Depletion, depreciation and amortization		143			15			257	46
Interest and other financing costs, net		(18,402)			(11,604)			(46,903)	(33,816)
Derivatives, net		0			0			0	0
Other expenses, net		145			(106)			(1,200)	(2,348)
Total costs and expenses		(13,308)			(1,634)			39,315	(17,629)
Income (loss) before income taxes		13,308			1,634			(39,315)	17,629
Income tax expense (benefit)		0			0			0	0
Net income (loss)		13,308			1,634			(39,315)	17,629
Consolidated capital expenditures, net		114,339			13,734			261,755	169,158
Property and equipment, net		1,225,991			822,013			1,225,991	822,013
Total assets		1,727,997			1,329,267			1,727,997	1,329,267
Operating Segments | U.S. Gulf of Mexico
Segment Reporting Information [Line Items]
Oil and gas revenue		116,603			96,626			441,446	298,905
Gain on sale of assets					0			471	0
Other income, net		698			256			1,726	1,028
Total revenues and other income		117,301			96,882			443,643	299,933
Oil and gas production		26,540			26,797			79,850	75,309
Facilities insurance modifications, net		0			0			0	0
Exploration expenses		2,674			13,975			19,770	20,541
General and administrative		2,804			4,177			11,181	12,620
Depletion, depreciation and amortization		32,701			37,551			115,648	124,598
Interest and other financing costs, net		2,785			3,446			8,244	12,307
Derivatives, net		0			0			0	0
Other expenses, net		(6,317)			648			11,355	26,185
Total costs and expenses		61,187			86,594			246,048	271,560
Income (loss) before income taxes		56,114			10,288			197,595	28,373
Income tax expense (benefit)		(275)			0			2,828	0
Net income (loss)		56,389			10,288			194,767	28,373
Consolidated capital expenditures, net		43,612			21,188			107,856	65,674
Property and equipment, net		881,990			925,384			881,990	925,384
Total assets		3,649,195			3,216,368			3,649,195	3,216,368
Corporate & Other
Segment Reporting Information [Line Items]
Oil and gas revenue		0			0			0	0
Gain on sale of assets					1,538			0	1,564
Other income, net		(82,537)			65,941			340,768	347,866
Total revenues and other income		(82,537)			67,479			340,768	349,430
Oil and gas production		0			0			0	0
Facilities insurance modifications, net		0			(1)			0	0
Exploration expenses		1,829			748			3,135	5,269
General and administrative		44,577			39,464			138,783	129,108
Depletion, depreciation and amortization		440			391			1,253	1,266
Interest and other financing costs, net		29,086			18,641			86,450	78,348
Derivatives, net		(113,842)			38,224			243,534	252,606
Other expenses, net		33			265			(834)	2,306
Total costs and expenses		(37,877)			97,732			472,321	468,903
Income (loss) before income taxes		(44,660)			(30,253)			(131,553)	(119,473)
Income tax expense (benefit)		2,204			1,645			4,703	6,196
Net income (loss)		(46,864)			(31,898)			(136,256)	(125,669)
Consolidated capital expenditures, net		1,834			(162)			4,545	5,564
Property and equipment, net		17,373			21,192			17,373	21,192
Total assets		18,987,516			14,315,531			18,987,516	14,315,531
Eliminations
Segment Reporting Information [Line Items]
Oil and gas revenue		0			0			0	0
Gain on sale of assets					0			0	0
Other income, net		81,886			(66,131)			(342,352)	(348,685)
Total revenues and other income		81,886			(66,131)			(342,352)	(348,685)
Oil and gas production		0			0			0	0
Facilities insurance modifications, net		0			0			0	0
Exploration expenses		0			0			0	0
General and administrative		(31,956)			(27,908)			(98,817)	(94,296)
Depletion, depreciation and amortization		0			0			0	0
Interest and other financing costs, net		0			0			0	(1,784)
Derivatives, net		0			0			0	0
Other expenses, net		113,842			(38,224)			(243,534)	(252,606)
Total costs and expenses		81,886			(66,132)			(342,351)	(348,686)
Income (loss) before income taxes		0			1			(1)	1
Income tax expense (benefit)		0			0			0	0
Net income (loss)		0			1			(1)	1
Consolidated capital expenditures, net		0			0			0	0
Property and equipment, net		0			0			0	0
Total assets		$ (23,784,949)			$ (16,859,275)			$ (23,784,949)	$ (16,859,275)

Business Segment Information _3

Business Segment Information - Consolidated Capital Expenditures (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Segment Reporting [Abstract]
Oil and gas assets			$ 543,349	$ 377,850
Acquisition of oil and gas properties			21,205	0
Proceeds on sale of assets			(118,703)	(5,327)
Changes in capital accruals			1,511	(16,523)
Exploration expense, excluding unsuccessful well costs and leasehold impairments			35,570	24,680
Capitalized interest			(57,489)	(31,956)
Other			8,259	4,686
Consolidated capital expenditures, net	$ 203,091	$ 86,046	$ 433,702	$ 353,410